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Initial Exam 2011-302 Final Administrative JPMs
	ML120480093
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Site:	Robinson
Issue date:	02/10/2012
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	Mark Bates
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Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01002100402 Task

Title:

Perform the RCS Leakage Surveillance JPM No.: 2011-2 NRC JPM Procedure Admin RO Al-i K/A

Reference:

G2.l.7 (RO 4.4)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant Task Standard: Candidate calculates the Unidentified and Identified Leakage.

Required Materials: OST-051 Reactor Coolant System Leakage Evaluation Station Curve 8.10, RCDT Level Calculator General

References:

OST-051 Reactor Coolant System Leakage Evaluation Station Curve 8.10, RCDT Level Handouts: OST-05i Reactor Coolant System Leakage Evaluation, Revision 45 marked up to the step for verifying current RCS temperature is equal to initial RCS temperature (Step 8.1.7.1). Attachment 10.1 must be marked with the initial parameter values and Attachment 10.5 marked with collected data.

Time Critical Task: NO Validation Time: 15 minutes 2011-2 NRC Admin JPM RO Al-I NUREG 1021, Revision 9, Supplement I

Appendix C Job Performance Measure Form ES-C-i Worksheet Initial Conditions: Plant is at 50% RTP.

You are the Reactor Operator.

Initiating Cue: The previous shift started OST-051, Reactor Coolant System Leakage Evaluation. The plant has remained at steady state, with NO automatic make-ups for ONE (1) hour.

Complete the provided procedure through Step 8.1.10.3.

These final parameter values were recorded 60 minutes after the procedure was started except as noted for PRT and RCDT levels:

RCS Temperature: 562°F

VCT Level: 20.8 inches

PZR Level: 45%

PZR RELIEF TANK: 70.9% (24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months data)

Accumulator A: 72%

Accumulator B: 71%

Accumulator C: 74%

RCDT: 19% (12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months data)

Charging Pump Leakoff Collection Tank: 32%

Attachment 10.5, Components with Known Measured Leakage, has leakage on valve LCV-i I 5B outlet flange that has been measured during the performance of OST-051 at 1000 ml in a 5 minute period.

2011-2 NRC Admin JPM RO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 8 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: i Candidate obtains copy of the marked up OST-051.

Standard: Candidate reviews the partially completed OST-051.

Examiners NOTE: Provide candidate with a copy of the marked up Procedur e

and Attachment.

Comment:

Performance Step: 2 WHEN at least 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months has elapsed, OR IF required by plant conditions to end this test, THEN perform the following: (Step 8.1.7.1, 2,3).

1. Verify RCS temperature is equal to initial RCS temperature recorded on Attachment 10.1.

2. Record the Final Values for the parameters listed on Attachment 10.1.

3. Verify LCV-i 1 5A, VCT HLDP TK DIV, in the AUTO position.

Standard: RCS temperature is equal to the initial RCS temperature at the beginning of the OST.

Final values have been recorded on Attachment 10.1.

LCV-1 1 5A control switch has been placed in the AUTO position.

Examiners NOTE:

Examiners CUE LCV-115A has been placed in AUTO.

Comment:

2011-2 NRC Admin JPM ROA1-1 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 8 Form ES-C-i PERFORMANCE INFORMATION Procedure NOTE: A decrease in VCT level represents plus (÷) RCS leakage.

A decrease in Pressurizer level represents plus (+) RCS leakage.

Performance Step: 3 Calculate the Difference and Change in Volume for the parameters listed on Attachment 10.1 (Step 8.1.8).

Standard: Operator completes the Difference and Change in Volume calculations as directed on Attachment 10.1 (See KEY).

Examiners NOTE:

Comment:

Performance Step: 4 Perform a peer check of the calculated values listed in Attachment 10.1. (Step 8.1.9)

Standard: Candidate requests a peer check for the calculations performed.

Examiners NOTE:

Examiners CUE: State that a peer check has been performed.

Comment:

2011-2 NRC Admin JPM ROA1-1 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 8 Form ES-C-i PERFORMANCE INFORMATION Procedure NOTE: A plus (+) calculated Total RCS Leakage Rate represents plus (+) RCS leakage.

Leak-rates (in gpm) on Aftachment 10.2 should be rounded to two decimal places.

Performance Step: S On Attachment 10.2, Perform the following: (Step 8.1.10)

Calculate the Total RCS Leakage Rate.

Calculate the Identified RCS Leakage Rate.

Calculate the Unidentified RCS Leakage Rate.

Perform a peer check of the calculations performed on Attachment 10.2.

Standard: Candidate completes the Total, Identified and Unidentified leakage calculations as directed on Attachment 10.2 (See KEY).

Candidate requests a peer check of the calculations performed on Attachment 10.2.

Examiners NOTE:

Examiners CUE: Once the RO candidate has performed the Total, Identified and Unidentified RCS Leakage Rate calculations, inform them that they have completed the JPM task.

Comment:

END OF TASK 2011-2 NRC Admin JPM ROA1-1 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 8 Form ES-C-i PERFORMANCE INFORMATION Termination Cue: When the RCS leakage rate calculation is completed, the evaluation for this JPM is complete.

STOP TIME:

2011-2 NRC Admin JPM RO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 8 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC Admin JPM RO Al-i Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC Admin JPM RO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 8 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: Plant is at 50% RTP.

You are the Reactor Operator.

INITIATING CUE: The previous shift started OST-05i, Reactor Coolant System Leakage Evaluation. The plant has remained at steady state, with NO automatic make-ups for ONE (1) hour.

Complete the provided procedure through Step 8.1.10.3.

These final parameter values were recorded 60 minutes after the procedure was started except as noted for PRT and RCDT levels:

RCS Temperature: 562°F

VCT Level: 20.8 inches

PZR Level: 45%

PZR RELIEF TANK: 70.9% (24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months data)

Accumulator A: 72%

Accumulator B: 71%

Accumulator C: 74%

RCDT: 19% (12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months data)

Charging Pump Leakoff Collection Tank: 32%

Attachment 10.5, Components with Known Measured Leakage, has leakage on valve LCV-i 1 SB outlet flange that has been measured during the performance of OST-OSi at 1000 ml in a 5 minute period.

2011-2 NRC Admin JPM ROA1-1 NUREG 1021, Revision 9, Supplement 1

Ai if Progres Eflfqy I Con&wous

) Use ROBINSON NUCLEAR PLANT PLANT OPERATING MANUAL VOLUME 3 PART 9 OST-051 REACTOR COOLANT SYSTEM LEAKAGE EVALUATIO N

(EVERY 72 HO URS DURING STEADY S TA TE OPER A TION A ND WITHIN 12 HO URS A FTER REA CHING STEAD Y

S TA TE OPERA TION)

REVISION 45 f OST-051 Rev. 45 Page 1 of 24

SUMMARY

OF CHANGES PRR #00448048 OST-051, Revision 45 STEP REVISION COMMENTS 8.1.14.3 Added PERFORM Peer Check of data entry field s prior to uploading any data. PRR 00448048 Note prior to Deleted V:\Drive Link and added 8.1.14 N :\NGGWEB\RNPDepartments\Operations\RC S Leakage Program PRR 00450337 Attachment 10.4 Added There is a single valve outside of containm note prior to ent to obtain this sample in pipe alley WD-1731A, RCDT Discharg 3.a.2.b e Header to WHUT Drain. PRR 00453076 Attachment 10.4 Revised step to notify E&RC to obtain sample 3.a.2.b and analyze for activity and boron concentration lAW CP-003.

OST-051 Rev. 45 Page 2 of 24

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE 4

2.0 REFERENCES

5 3.0 RESPONSIBILITIES 6

4.0 PREREQUISITES 6

5.0 PRECAUTIONS AND LIMITATIONS 7

6.0 SPECIAL TOOLS AND EQUIPMENT 8

7.0 ACCEPTANCE CRITERIA 8

8.0 PROCEDURE 8.1 RCS Leakage Rate Test 9 9

9.0 RECORDS 14 10.0 ATTACHMENTS 10.1 LEAKAGE EVALUATION DATA SHEET 14 10.2 LEAKAGE EVALUATION CALCULATION 15 SHEET 17 10.3 LEVEL TO GALLONS CONVERSION TABL E 18 10.4 ACTION LEVEL RESPONSE GUIDELINES 10.5 COMPONENTS WITH KNOWN MEASURED 19 LEAKAGE 23 10.6 SURVEILLANCE TEST PROCEDURE CERT IFICATION AND REVIEW FORM 24 J OST-051 Rev. 45 Page 3 of 24

1.0 PURPOSE 1.1 To evaluate RCS leakage and to satisfy Impr oved Technical Specification Surveillance Requirement (ITS SR) 3.4.13.1.

1.2 This test is required when in Modes 1,2, 3 or4. ITS SR 3.4.13.1 basis further defines the applicable conditions as within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reaching continuous steady state operation.

1.3 This test may be performed when in Mode 5 as long as the RCS is pressurized, there is a bubble in the Pressurizer and RCS

/RHR temperature is constant.

However, a test under these conditions will not satisfy ITS SR 3.4.13.1.

1.4 This procedure supports the License Renewal Aging Management Program Boric Acid Corrosion Program by providing RCS leakage monitoring criteria (Reference 2.11).

J OST-051 Rev. 45 Page 4 of 24

2.0 REFERENCES

2.1 Improved Technical Specifications LCO 3.4.13 and ITS 1.1 Defini tion of LEAKAGE 2.2 AP-030, NRC Reporting Requirements 2.3 EPCLA-01, Emergency Control 2.4 EGR-NGGC-0207, Boric Acid Corrosion Control (Generic Letter 88-05) 2.5 AOP-016, Excessive Primary Plant Leakage 2.6 OMM-015, Operations Surveillance Testing 2.7 ESR 94-471, Calculation for VCT Level vs. Volume 2.8 PLP-037, Conduct of Infrequently Performed Test or Evolutions and Pre-Job Briefs 2.9 CP-014, Primary-To-Secondary Leak Rate Calculation 2.10 SOER 97-1, Potential Loss of High Pressure Injection and Charging from Gas Intrusion (Credit taken for monitoring VCT level to address recomm endation #1 of the SOER) 2.11 RNP-LILR-0601, Aging Management Program, Boric Acid Corros ion Program 2.12 PWROG Letter, OG-07-286, Dated June 26, 2007 entitled Recom mendations for Implementation of Guidelines for PWROG RCS Leak Rate Progra ms 2.13 PWROG Letter, OG-08-400 Dated November 19, 2008 entitled Clarif ication of the Recommendation of Guidelines for PWROG RCS Leakage Rate Program with Respect to NEI-03-08 (PA-OSC-0189 and PA-OSC-0218) 2.14 WCAP-16423-NP, Pressurized Water Reactor Owners Group Standa rd Process and Methods for Calculating RCS Leak Rate for Pressurized Water Reactors 2.15 WCAP.-16465-NP, Pressurized Water Reactor Owners Group Standa rd RCS Leakage Action Levels and Response Guidelines LOST-051 Rev. 45 Page 5 of 24

3.0 RESPONSIBILITIES 3.1 Operations is responsible for:

3.1.1 Performance, review, and approval of this test.

3.1.2 Updating of the RCS Leakage Monitoring Spreadsheet after each performance of the surveillance.

3.2 Engineering is responsible for:

3.2.1 Development and maintenance of the RCS Leakage Monitoring Spreadsheet.

3.2.2 Establishment and updating of baseline mean (p) and standa rd deviation (a) values.

4.0 PREREQUISITES 4.1 This revision has been verified to be the 4.2 The Shift Manager has given permission to conduct this test.

4.3 RCS temperature is stable.

4.4 There is a bubble in the Pressurizer NOTE: ITS SR 3.413.1 requires performance of this test within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reaching steady state operating conditions in Modes 1, 2, 3, or 4. This test may be performed when stable in Mode 5 but only for tracking and trending purposes, not to satisfy the ITS SR requirements.

4.5 RCS pressure is stable.

4.6 Record RCS pressure.

2 Zz5psig 4.7 Record Plant Mode. Mode

(

J OST-051 Rev. 45 Page 6 of 24

5.0 PRECAUTIONS AND LIMITATIONS 5.1 The accuracy of the RCS Leakage Rate Test is greatly improved when RCS temperature and Pressurizer level remain constant for the duration of the test.

5.2 This procedure should not be started unless the VCT level is high enough to avoid an automatic makeup during the performance of the RCS Leakage Rate Test.

5.3 Any steps not applicable shall be marked N/A and the reason(s) for any N/A noted in the Comments section of Attachment 10.6.

5.4 The principles of ALARA shall be used in planning and performing work and operations in the Radiation Control Area.

5.5 This procedure has been screened lAW PLP-037 criteria and determined to be outside the bounds of an Infrequently Performed Test or Evolution.

5.6 IF RCS pressure boundary LEAKAGE is verified, THEN the reactor shall be placed in Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in Mode 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months of discovery of pressure boundary leakage. Pressure boundary LEAKAGE is leakage (except SG leakage) through a non-isolable fault in an RCS com ponent body, pipe wall, orvessel wall. (ITS [CO 3.4.13) 5.7 For the purpose of this procedure, IDENTIFIED RCS Leak age is leakage collected in either the PRT, the RCDT, a Safety Injection Accum ulator, or the Charging pump Seal Leak-off Collection Tank. This type of RCS leakage is through seat leakage, NOT through wall OR RCS Pressure Boundary (RCPB) leakage. This type leakage is NOT to be confused with Miscel laneous Identified RCS Leakage as it may be related to interconnected syste ms outside the RCS Pressure Boundary (See P&L 5.13).

5.8 Whenever possible, use the ERFIS Computer for data collect ion. This will improve accuracy and reduce the potential for human error.

5.9 The ERFIS on-screen historic information may be used to assist with data collection. This is especially helpful during xenon transients or when in AOP-016, Excessive Primary Plant Leakage.

5.10 To improve the accuracy of the Pressurizer Relief Tank (PRT) level changes calculated during this procedure, a long term trend should be used for data collected from ERFIS. Duration of the long term PRT trend should be any period of stable PRT operation up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Due to possible evolutions affecting the PRT, the duration of the trend will be decided by the operator performing this test.

OST-051 Rev. 45 Page 7 of 24

5.11 IF R-1 1 is increasing and cannot be attributed to any specific leak location based on search results with the unit on line, THEN a task should be added to the forced outage schedule to inspect normally inaccessible areas for indication of leakage to the maximum extent practical.

5.12 To improve the accuracy of the Reactor Coolant Drain Tank (RCDT) level changes calculated during this procedure, a long term trend should be used for data collected from LI-i 003. Duration of the long term RCDT trend should be any period of stable RCDT operation up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Due to possible evolutions affecting the RCDT, the duration of long term trend will be determined by the SMICRS.

5.13 Component leakage (valve packing, pump seal, fitting leakage, etc.) from accessible sources may only be treated as Miscellaneous Identified leakage if the source has been identified AND the actual value of the leakage is obtain ed by a measurement taken at the start or during the data taking interval for the surveillance test. The leakage must be measured each time the OST is performed if it is to be credited towards Miscellaneous Identified RCS Leakage.

Each component leak must have an active Work Order.

5.14 This procedure has been reviewed and found to be not applicable as per the requirements of OPS-NGGC-1 306, Reactivity Management.

6.0 SPECIAL TOOLS AND EQUIPMENT 6.1 Calibrated Stop Watch (If needed to collect Miscellaneous RCS Identified Leakage) 6.2 Graduated Container (If needed to collect Miscellaneous RCS Identified Leakage) 7.0 ACCEPTANCE CRITERIA 7.1 This test is acceptable if

- Unidentified RCS Leakage Rate does NOT exceed 1 gpm

- Identified RCS Leakage Rate does NOT exceed 10 gpm

- Primary-to-Secondary leakage does NOT exceed 75 gpd through any one steam generator as determined by CP-014.

7.2 The reviewing and approving authorities may accept this test in accordance with provisions set forth in OMM-015, Operations Surveillance Testing.

OST-051 I Rev. 45 Page 8 of 24

Section 8.1 Page 1 of 5 8.0 PROCEDURE INIT 8.1 RCS Leakage Rate Test 8.1.1 VERIFY RCS MAKEUP MODE in the AUTO position.

8.1.2 VERIFY RCS MAKEUP SYSTEM is ON.

8.1.3 IF desired, THEN PLACE LCV-115A, VCT/HLDP TK Dlv, in the VCT position.

41/A NOTES: Whenever possible, use the ERFIS computer for data collect ion. This will improve accuracy and reduce the potential for human error.

The ERFIS on-screen historic information may be used to assist with data collection. This is especially helpful during a xenon trans ient or when in AOP-016, Excessive Primary Plant Leakage.

Measurement of leakage in Step 8.1.4.c, and the calcu lation of Total Measured Leakage in Step 8.1.4.d may be performed immed iately prior to or at any time during the duration of this test.

The following step may be N/A if there is no active leaka ge issuing from components previously identified by work order.

8.1.4 IF there are any components that have known, active leakage, where the source is identified and can be treated as Miscellaneous Identified RCS Leakage or Known Non-RCPB Leakage per P&L 5.7 and P&L 5.13, THEN PERFORM the following on Attachment 10.5:

a. LIST the actively leaking component(s)

b. RECORD the Work Order number(s) for the component(s)

c. RECORD the measured leakage for the component(s)

d. CALCULATE the Total Measured Leakage Peer Check 8.1.5 RECORD the Initial Values for the parameters listed on Attachment 10.1.

f OST-051 Rev. 45 Page 9 of 241

Section 8.1 Page 2 of 5 INIT 8.1.6 IF an automatic makeup occurs, THEN PERFORM the following:

1. VERIFY LCV-115A, VCT/HLDP TK Dlv, in the AUTO position.

2. STOP this procedure AND NOTE reason in Comments section.

NOTES: When this procedure is being performed to satisfy ITS SR 3.4.13.1, the preferred duration is greater than or equal to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and the minimum duration 15 minutes.

When this procedure is being performed as directed by an AOP, there is not a minimum duration requirement.

8.1.7 WHEN at least 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months has elapsed, OR, IF required by Plant conditions to end this test, THEN PERFORM the following:

1. VERIFY RCS temperature is equal to initial RCS temperature recorded on Attachment 10.1.

2. RECORD the Final Values for the parameters listed on Attachment 10.1.

3. VERIFY LCV-1 15A, VCT/HLDP TK DIV, in the AUTO position.

NOTES: A decrease in VCT level represents plus (+/-) RCS leakage.

A decrease in Pressurizer level represents plus (÷) RCS leakage.

8.1.8 CALCULATE the Difference and Change in Volume for the parameters listed on Attachment 10.1.

8.1.9 PERFORM a peer check of the calculated values listed in Attachment 10.1.

OST-051 Rev. 45 Page 10 of 24

Section 8.1 Page 3 of 5 INIT NOTES: A plus (+) calculated Total RCS Leakage Rate represents plus (+) RCS leakage.

Leak-rates (in gpm) on Attachment 10.2 should be rounded to two decimal places.

8.1.10 On Attachment 10.2, PERFORM the following:

1. CALCULATE the Total RCS Leakage Rate.

2. CALCULATE the Identified RCS Leakage Rate.

3. CALCULATE the Unidentified RCS Leakage Rate.

4. PERFORM a peer check of the calculations performed on Attachment 10.2 8.1.11 IF unidentified RCS leakage is greater than 1.0 gpm OR the identified RCS leakage is greater than 10 gpm, THEN PERFORM the following:

1. CONSULT ITS LCO 3.4.13 for required actions.

2. CONSULT AP-030 for reporting requirements.

3. CONSULT EPCLA-01 for emergency action levels.

4. CONSULT AOP-016 for required actions.

8.1.12 IF RCS unidentified leakage is 0.05 gpm AND any valid R-24 monitor alarm OR any R-19 monitor indicates an increasing trend, THEN contact E&C Technician to perform Primary to Secondary Leakage Calculation for each steam generator in accordance with CP-014. (ITS [CO 3.4.13.d)

Primary to Secondary Leakage___________ gpd OST-051 Rev. 45 Page 11 of 24]

Section 8.1 Page 4 of 5 I NIT 8.1.13 IF unidentified RGS leakage is equal to or greater than 0.03 gpm for 3 consecutive leak rate calculations, THEN perform the following:

1. Start an investigation immediately and inform plant staff.

2. IF not currently in progress, THEN start daily leak rate calculations.

NOTE: The RCS Leakage Monitoring Spreadsheet can be located at N:\NGGWEB\RNP\Departments\Operations\RCS Leakage Program or accessed from the OPS Tool Database 8.1.14 Update the RCS Leakage Monitoring Spreadsheet as follow s:

1. LOG date and time.

2. ENTER RCS Identified and Unidentified RCS leakage.

3. PERFORM Peer Check of data entry fields prior to uploading any data.

4. CLICK UPLOAD DATA.

8.1.15 RECORD the following Unidentified Leak Rate data from the RCS Leakage Monitoring Spreadsheet:

1. Current Mean (p) value

2. Current Sigma (a) value

3. Current [p + 2cr] value

4. Current [p + 3cr] value

5. 7 Day Rolling Average

6. Number of Consecutive Days greater than (p)

7. Last 3 Daily Unidentified Leak Rates J OST-051 Rev. 45 Page 12of241

Section 8.1 Page 5 of 5 INIT 8.1.16 Evaluate Unidentified Leakage against the Action Level Criteria Below:

Action Action Level Level Action Level Limit Description Exceeded (Circle One)

Tier One 7-day rolling average of daily Unidentified RCS leak rates is greater than 0.1 gpm YES i NO Action Level Nine consecutive daily unidentified RCS leakage values> mean (p) YES / NO Tier Two Two consecutive daily Unidentified RCS leak rates_are_greater than_0.15_gpm YES NO Action Level Two of three consecutive daily Unidentified leak rates_greater than_[p+2a} YES NO Tier Three One daily Unidentified RCS leak rate is greater than 0.3 gpm YES / NO Action Level I One daily Unidentified RCS leak rate is greater than [p+3aJ YES NO 8.1.17 IF any Unidentified RCS leakage Action Level (AL) is exceeded, THEN PERFORM the following:

1. REVIEW and implement the appropriate actions of Attachment 10.4, Action Level Response Guidelines while continuing with this procedure.

2. INITIATE an Action Plan lAW PLP-121 to document actions taken.

8.1.18 UPDATE leakage rate on Control Room status board.

8.1.19 IF Attachment 10.4, Action Level Response Guidelines was required, THEN ATTACH it to this OST when submitting to Records.

OST-051 Rev. 45 Page 13 of 24

INIT 9.0 RECORDS 9.1 Completed procedure, included completed partials shall be retained as a non permanent QA record 10.0 ATTACHMENTS 10.1 Leakage Evaluation Data Sheet 10.2 Leakage Evaluation Calculation Sheet 10.3 Level to Gallons Conversion Table 10.4 Action Level Response Guidelines 10.5 Components with Known Measured Leakage 10.6 Surveillance Test Procedure Certification and Review Form J OST-051 Rev. 45 Page 14 of 24

ATTACHMENT 10.1 Page 1 of 2 LEAKAGE EVALUATION DAT A SHEET flrn,rnan+e OST-051 Rev. 45 Page 15 of 24

0 e .

ATTACHMENT 10.1 Page 2 of 2 (1) Use Curve Book, Curve 8.23 or Attachment 10.3, to conver (2) Use Curve Book, Cur t PRT level into gallons OR ve 8.10, to convert RCDT leve mark as N/A if level did not incr of the Reactor Coolant Drain l into gallons QE mark as N/A ease.

if level did not increase. To data collected from LI-i 003.

Tank (RCDT) level changes calculated during this procedure imp rov e the accuracy A spreadsheet was developed , a long term trend should be file is located at V:\Operations to log RCDT levels that would used for

\STA\RCDT Level. This gra provide a graph of the RCDT Tre into the RCDT. Duration of the ph or an ERFIS plot should be monito nd. The long term RCDT trend should red for changes in inleakage rate duration of long term trend will be any period of stable RCDT s be determined by the SM/CRS). operation up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . (Actual (3) Use Curve Book, Curve 8.22 or Attachment 103, to con N/A if level did not increase. vert Charging Pump Leak-off Collection Tank level into gallons (4) Minimum test duration or mark as of 15 minutes is required when performing this procedure to satisfy (5) Circle the respective ind icator/indication used. IF ERFIS ITS SR 3.4.13.1.

THEN obtain the values from the is in service, THEN use it to obtain respective RTGB indicators AND values. IF ERFIS is not in service, were used for the OST. make a comment in the Commen ts section that RTGB indicators (6) An increase in SI Accum ulator is (+) RCS Leakage. IF the another, THEN do not include the increase is due to SI Accumulators change in the identified RCS leak sluicing from one accumulator to ONLY IF RCS pressure is less than age rate. A decrease in SI Accum SI Accumulator pressure. ulator is (-) RCS leakage (7) PZR RELIEF TANK Level Initial & Final should be collected Operation. An ERFIS plot should be from ERFIS using long term trend monitored for changes in inleakage up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of Stable PRT should be any period of stable PRT rates into the PRT. Duration of the operation up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . (Actual long term PRT trend duration of long term trend will be determined by the SM/CRS)

OST-051 Rev. 45 Page 16 of 24

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ATTACHMENT 10.3 Page 1 of 1 LEVEL TO GALLONS CONVERSION TABLE Charging Pump Leakoff Collection Tank Curve 8.22 Pressurizer Relief Tank 8.23 Level Gallons Level Gallons Indicated Level Gallons Level Gallons Indicated Indicated

% Indicated 1

0.17 51 22.00 711 0 2 7075.00 7S I 7572.25 0.33 52 22.66 70.1 3 7084.75 75.2 7582.00 0.50 53 23.17 70.2 4 05 54 7094.5.0_..._.. 75.3 7591.75 23.66. 70.3 11Q425 75.4 7601.50 5 55 24.17 6 70.4 7114.00 75.5 7611.25 111. 56 24.66 70.5 7123.75 7 57 75.6 7621.00 25.33 70.6 7133.50 75.7 8 58 7630.75 25.84 70.7 7143.25 75.8 9 2.00 59 7640.50 26.33. 70.8 7153.00 75.9 .7959.25 10 2.33 60 26.84 11 70.9 7162.75 76.0 7660.00 2.66 61 27.51 71.0 12 7172.50 76.1 7669.75 I0I 62 28.00 71.1 13 7182.25 76.2 7679.50 3.33 63 28.50 71,2 14 7192.00 76.3 7689.25 3.66 64 29.00 71.3 15 7201.75 76.4 7699.00 4.00 65 29.33 71.4 16 7211.50 76.5 7708.75 4.33 66 3017 71.5 17 7221.25 76.6 7718.50 4.66 67 30.66 71.6 18 7231.00 76.7 7728.25 5.33 68 31.17 71.7 19 7240.75 76.8 1Z38.00 5.66 69 31.66 71.8 20 725050 76.9 7747.75 6.00 70 32.17 71.9 21 7260.25 77.0 7757.50 6.50 71 32.6& 72.0 22 7270.00 77.1 7767.25 7.00 72 33.3.1 72.1 23 7279.75 77.2 7777.00 7.33 73 33.66 72.2 24 7289.50 77.3 7786.75 7.84 74 34.33 72.3 25 7299.25 77.4 7796.50 8.33 75 34.66 72.4 26 7309.00 77.5 7806.25 8.83 76 35.17 72.5 27 7318.75 77.6 7816.00 9.33. 77 35.6& 72.6 28 7328.50 77.7 7825.75 9.84 78 36.0(1 72.7 29 7338.25 77.8 7835.50 10.33 79 36.5(1 72.8 30 7348.00 77.9 7845.25 10.83 80 36.84 31 11.33 81 129 7357.75 78.0 7855.00 37.33 73.0 7367.50 78.1 7864.75 32 11.84 82 37.56 73.1 7377.25 78.2 7874.50 33 12.33 83 38.00 73.2 7387.00 78.3 34 13.00 84 7884.25 35 38.50 73.3 7396.75 78.4 7894.00 13.49 85 38.83 73.4 36 7406.50 78.5 7903.75 14.00 86 39.17 73.5 37 7416.25 78.6 7913.50 14.66 87 39.66 73.6 38 15.18 88 1426.00 78.7 7923.25 40(10 73.7 7435.75 78.8 7933.00 39 15.66 89 40.33 40 73.8 7445.50 78.9 7942.75 16.17 90 40.50 73.9 41 i45..25 79.0 7952.50 16 91 40.84 74.0 42 7465.00 79.1 7962.25 17.00 92 41.00 74.1 43 7474.75 79.2 197Z00 17,66 93 4zL3..3..

44 74.2 144.56..._..... 79.3 1981.75 18,33 94 41.66 74.3 45 7494.25 79.4 .7991.50 18.83. 95 41.83 74.4 46 19.33 1594.00 79.5 8001.25 96 41B4 74.5 7513.7&.._... 79.6 47 20.00 97 8011.00 42.33 74.6 7523.50 79.7 48 20.50 98 42.66 74.7 153.3.25 79.8 8030.50 49 21.00 99 50 42.81 74.8 154I0cL_... 79.9 8040.25 21.50 100 43.00 74.9 72 75 80.0 Rfl50 00 75.0 7562.50 OST-051 Page 18 of 24

ATTACHMENT 10.4 Page 1 of4 ACTION LEVEL RESPONSE GUIDELINES DEFINITIONS: Daily means the daily average value which is the average of all valid measurements performed on a given calendar day.

MEAN (p) Average of the valid leak rates for a given period of time.

STANDARD DEVIATION (a) A measure of the degree of dispersion of the data from the mean value.

NOTE: Daily for below Action Levels should be interpreted as periodic if the ULR measurements are performed on less than a daily basis. That is, a periodic value is always a daily average value but is not evaluated calendar day.

every INIT Response Guidelines for Exceeding Tier One Action Levels

a. IF one 7-day rolling average of daily Unidentified RCS leak rates is greater than 0.1 gpm OR nine consecutive daily unidentified RCS leakage values > mean THEN PERFORM the following:

1) CONFIRM indication.

2) PERFORM a confirmatory leak rate calculation.

3) CHECK for abnormal trends on other leakage indicators.

4) FORWARD data to Engineering to evaluate trends.

5) INCREASE monitoring as recommended by Engineering.

6) INITIATE a condition report. NCR #

7) NOTIFY Operations Management

( OST-051 Rev. 45 Page 19 of 24

ATTACHMENT 10.4 Page 2 of 4 ACTION LEVEL RESPONSE GUIDELINES INIT

2. Response Guidelines for Exceeding Tier Two Action Levels

a. IF two consecutive daily Unidentified RCS leak rates are greater than 0.15 gpm OR two of three consecutive daily Unidentified leak rates greater than [p+2o], THEN PERFORM the following:

1) VERIFY Tier One response guidelines have been performed.

2) COMMENCE a leak investigation as follows:

.a) REVIEW recent plant evolutions.

.b) EVALUATE changes in other leakage detection indications.

.c) INITIATE walkdowns of various portions of potentially affected systems outside containment.

3) IDENTIFY the source of the increase in leakage as follows:

.a) CHECK any components OR flow paths recently changed or placed in service, shutdown, vented, drained, or filled.

.b) CHECK any maintenance activity that may have resulted in increasing leakage.

.c) CHECK any filters recently alternated OR changed for leakage from their vents or drains.

INSPECT filter housing for gaskets leakage.

CHECK seal injection filters AND reactor coolant filter for signs of leakage.

4) NOTIFY Operations Management OST-051 Rev. 45 Page 20 of 24

ATTACHMENT 10.4 Page 3 of 4 ACTION LEVEL RESPONSE GUIDELINES INIT

3. Response Guidelines for Exceeding Tier Three Action Levels

a. IF one daily Unidentified RCS leak rate is greater than 0.3 gpm OR

[p+3aJ, THEN PERFORM the following:

1) VERIFY Tier One AND Tier Two response guidelines have been performed.

2) IF increased leak rate is indicated inside containment, THEN PERFORM the following:

.a) BEGIN PLANNING for a containment entry.

NOTE: There is a single valve outside of containment to obtain this sample in pipe alley WD-1731A.

.b) NOTIFY E&RC to OBTAIN a containment sump sample (during pump out) AND analyze for activity and boron concentration lAW CP-003, (looking for a larger than expected boric acid concentration OR other unexpected chemicals).

E&RC NOTIFIED

.c) EVALUATE other systems for indications of leakage.

.d) OBTAIN a containment atmosphere sample for indications of RCS leakage.

J OST-051 Rev. 45 Page 21 of 24

ATTACHMENT 10.4 Page 4 of 4 ACTION LEVEL RESPONSE GUIDEUNES INIT 3.0 (Continued) Response Guidelines for Exceeding Tier Three Action Levels

3) IDENTIFY the source of the leak.

4) QUANTIFY the leakage.

5) INITIATE a plan to repair the leak.

6) MONITOR containment airborne radiation levels AND area radiation monitors.

7) SAMPLE containment atmosphere for indications of RCS leakage.

8) MONITOR other containment parameters (temperature, pressure, humidity, etc.).

9) IF the leak source is found AND isolated OR stopped, THEN RE-PERFORM RCS leak rate calculation.

10) NOTIFY Operations Management OST-051 Rev. 45 Page 22 of 24

ATTACHMENT 10.5 Page 1 of 1 COMPONENTS WITH KNOWN MEASURED LEAKAGE I NOTE: If leakage can NOT be collected in a suitable container to accurately measure in milliliters per minute (such as when leakage is in a high dose area but can be viewed by camera), this drops per minute conversion may be used. To convert drops per minute to gallons per minute, multiply drops per minute by 1.32 x 10-5 (0.0000132). The drop counting method shall only be allowed if NO other means is available to measure leakage due to inaccessibility from a radiation dose or personnel safety standpoint based on CRS/SM guidance.

To convert milliliters per minute to gallons per minute, multiply milliliters per minute by 2.64 x 10 (0.000264). This is the preferred method for calculating leakage.

Individual component leakage should not be rounded. Rounding should be completed in the Total Measured Leakage calculation to 2 significant digits, as this is what will be used by the Leak Rate program.

Measured I Measured Duration Component Leakage Leakage Active Work Time (gpm) Volume Order Number DU7 k

1 t c / , I A4/

d 1 . Zo//- YX?G F/As I. F f

... I

-J Total Measured Leakage

( gpm

( OST-051 Rev. 45 Page 23 of 24

ATTACHMENT 10.6 Pagelofi SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM (Circle one)

(If unscheduled, state reason for test and the page numbers include d in partial test)

Test Performed By:

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1

) qn ne Test Complete: Date:___________ Time:_____________

Test Satisfactory: Yes I No (Circle one)

Reviewed by:

Shift Technical Advisor Date Comments: (Required if results were unsatisfactory)

Approved by:

Shift Manager Date J OST-051 Rev. 45 Page 24 of 24j

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Appendix C Page 8 of 8 Form ES-C-I JPM CUE SHEET INITIAL CONDITIONS: Plant is at 50% RTP.

You are the Reactor Operator.

INITIATING CUE: The previous shift started OST-051, Reactor Coolant System Leakage Evaluation. The plant has remained at steady state, with NO automatic make-ups for ONE (1) hour.

Complete the provided procedure through Step 8.1.10.3.

These final parameter values were recorded 60 minutes after the procedure was started except as noted for PRT and RCDT levels:

RCS Temperature: 562°F

VCT Level: 20.8 inches

PZR Level: 45%

PZR RELIEF TANK: 70.9% (24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months data)

Accumulator A: 72%

Accumulator B: 71%

Accumulator C: 74%

RCDT: 19% (12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months data)

Charging Pump Leakoff Collection Tank: 32%

Attachment 10.5, Components with Known Measured Leakage, has leakage on valve LCV-1 1 5B outlet flange that has been measured during the performance of OST-051 at 1000 ml in a 5 minute period.

2011-2 NRC Admin JPM ROAI-1 NUREG 1021, Revision 9, Supplement 1

C Progress Ener:y Continuous Use ROBINSON NUCLEAR PLANT PLANT OPERATING MANUAL VOLUME 3 PART 9 OST-051 REACTOR COOLANT SYSTEM LEAKAGE EVALUATION (EVERY 72 HO URS DURING STEADY S TA TE OPERA TION AND WITHIN 12 HOURS AFTER REACHING STEADY S TA TE OPERA TION)

REVISION 45 OST-051 Rev. 45 Page 1 of 24

SUMMARY

OF CHANGES PRR #00448048 OST-051, Revision 45 STEP REVISION COMMENTS 8.1.14.3 Added PERFORM Peer Check of data entry fields prior to uploading any data. PRR 00448048 Note prior to Deleted V:\Drive Link and added 8.1.14 N:\NGGWEB\RNP\Departments\Operations\RCS Leakage Program PRR 00450337 Attachment 10.4 Added There is a single valve outside of containment to obtain this note prior to sample in pipe alley WD-1731A, RCDT Discharge Header to WHUT 3.a.2.b Drain. PRR 00453076 Attachment 10.4 Revised step to notify E&RC to obtain sample and analyze for 3.a.2.b activity and boron concentration lAW CP-003.

OST-051 Rev. 45 Page 2 of 24

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE .4

2.0 REFERENCES

5 3.0 RESPONSIBILITIES 6 4.0 PREREQUISITES 6 5.0 PRECAUTIONS AND LIMITATIONS 7 6.0 SPECIAL TOOLS AND EQUIPMENT 8 7.0 ACCEPTANCE CRITERIA 8 8.0 PROCEDURE 9 8.1 RCS Leakage Rate Test 9 9.0 RECORDS 14 10.0 ATTACHMENTS 14 10.1 LEAKAGE EVALUATION DATA SHEET 15 10.2 LEAKAGE EVALUATION CALCULATION SHEET 17 10.3 LEVEL TO GALLONS CONVERSION TABLE 18 10.4 ACTION LEVEL RESPONSE GUIDELINES 19 10.5 COMPONENTS WITH KNOWN MEASURED LEAKAGE 23 10.6 SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM 24 OST-051 Rev. 45 Page 3 of 24

1.0 PURPOSE 1.1 To evaluate RCS leakage and to satisfy Improved Technical Specification Surveillance Requirement (ITS SR) 3.4.13.1.

1.2 This test is required when in Modes 1, 2, 3 or 4. ITS SR 3.4.13.1 basis further defines the applicable conditions as within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reaching continuous steady state operation.

1.3 This test may be performed when in Mode 5 as long as the RCS is pressurized, there is a bubble in the Pressurizer and RCS/RHR temperature is constant.

However, a test under these conditions will not satisfy ITS SR 3.4.13.1.

1.4 This procedure supports the License Renewal Aging Management Program Boric Acid Corrosion Program by providing RCS leakage monitoring criteria (Reference 2.11).

OST-051 Rev. 45 Page 4 of 24

2.0 REFERENCES

2.1 Improved Technical Specifications LCO 3.4.13 and ITS 1.1 Definition of LEAKAGE 2.2 AP-030, NRC Reporting Requirements 2.3 EPCLA-01, Emergency Control 2.4 EGR-NGGC-0207, Boric Acid Corrosion Control (Generic Letter 88-05) 2.5 AOP-016, Excessive Primary Plant Leakage 2.6 OMM-015, Operations Surveillance Testing 2.7 ESR 94-471, Calculation forVCT Level vs. Volume 2.8 PLP-037, Conduct of Infrequently Performed Test or Evolutions and Pre-Job Briefs 2.9 CP-014, Primary-To-Secondary Leak Rate Calculation 2.10 SOER 97-1, Potential Loss of High Pressure Injection and Charging from Gas Intrusion (Credit taken for monitoring VCT level to address recommendation #1 of the SOER) 2.11 RNP-L/LR-0601, Aging Management Program, Boric Acid Corrosion Program 2.12 PWROG Letter, OG-07-286, Dated June 26, 2007 entitled Recommendations for Implementation of Guidelines for PWROG RCS Leak Rate Programs 2.13 PWROG Letter, OG-08-400 Dated November 19, 2008 entitled Clarification of the Recommendation of Guidelines for PWROG RCS Leakage Rate Program with Respect to NEI-03-08 (PA-OSC-0189 and PA-OSC-0218) 2.14 WCAP-16423-NP, Pressurized Water Reactor Owners Group Standard Process and Methods for Calculating RCS Leak Rate for Pressurized Water Reactors 2.15 WCAP-16465-NP, Pressurized Water Reactor Owners Group Standard RCS Leakage Action Levels and Response Guidelines OST-051 Rev. 45 Page 5 of 24

3.0 RESPONSIBILITIES 3.1 Operations is responsible for:

3.1.1 Performance, review, and approval of this test.

3.1.2 Updating of the RCS Leakage Monitoring Spreadsheet after each performance of the surveillance.

3.2 Engineering is responsible for:

3.2.1 Development and maintenance of the RCS Leakage Monitoring Spreadsheet.

3.2.2 Establishment and updating of baseline mean (p) and standard deviation (a) values.

4.0 PREREQUISITES 4.1 This revision has been verified to be the latest revision available.

4.2 The Shift Manager has given permission to conduct this test.

4.3 RCS temperature is stable.

4.4 There is a bubble in the Pressurizer NOTE: ITS SR 3.4.13.1 requires performance of this test within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reaching steady state operating conditions in Modes 1, 2, 3, or 4. This test may be performed when stable in Mode 5 but only for tracking and trending purposes, not to satisfy the ITS SR requirements.

4.5 RCS pressure is stable.

4.6 Record RCS pressure. 23psig 4.7 Record Plant Mode. Mode f .

OST-051 Rev. 45 Page 6 of 24

5.0 PRECAUTIONS AND LIMITATIONS 5.1 The accuracy of the RCS Leakage Rate Test is greatly improved when RCS temperature and Pressurizer level remain constant for the duration of the test.

5.2 This procedure should not be started unless the VCT level is high enough to avoid an automatic makeup during the performance of the RCS Leakage Rate Test.

5.3 Any steps not applicable shall be marked N/A and the reason(s) for any N/A noted in the Comments section of Attachment 10.6.

5.4 The principles of ALARA shall be used in planning and performing work and operations in the Radiation Control Area.

5.5 This procedure has been screened lAW PLP-037 criteria and determined to be outside the bounds of an Infrequently Performed Test or Evolution.

5.6 IF RCS pressure boundary LEAKAGE is verified, THEN the reactor shall be placed in Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in Mode 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months of discovery of pressure boundary leakage. Pressure boundary LEAKAGE is leakage (except SG leakage) through a non-isolable fault in an RCS component body, pipe wall, or vessel wall. (ITS LCO 3.4.13) 5.7 For the purpose of this procedure, IDENTIFIED RCS Leakage is leakage collected in either the PRT, the RCDT, a Safety Injection Accumulator, or the Charging pump Seal Leak-off Collection Tank. This type of RCS leakage is through seat leakage, NOT through wall OR RCS Pressure Boundary (RCPB) leakage. This type leakage is NOT to be confused with Miscellaneous Identified RCS Leakage as it may be related to interconnected systems outside the RCS Pressure Boundary (See P&L 5.13).

5.8 Whenever possible, use the ERFIS Computer for data collection. This will improve accuracy and reduce the potential for human error.

5.9 The ERFIS on-screen historic information may be used to assist with data collection. This is especially helpful during xenon transients or when in AOP-016, Excessive Primary Plant Leakage.

5.10 To improve the accuracy of the Pressurizer Relief Tank (PRT) level changes calculated during this procedure, a long term trend should be used for data collected from ERFIS. Duration of the long term PRT trend should be any period of stable PRT operation up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Due to possible evolutions affecting the PRT, the duration of the trend will be decided by the operator performing this test.

OST-051 Rev. 45 Page 7 of 24

5.11 IF R-i 1 is increasing and cannot be attributed to any specific leak location based on search results with the unit on line, THEN a task should be added to the forced outage schedule to inspect normally inaccessible areas for indication of leakage to the maximum extent practical.

5.12 To improve the accuracy of the Reactor Coolant Drain Tank (RCDT) level changes calculated during this procedure, a long term trend should be used for data collected from LI-i 003. Duration of the long term RCDT trend should be any period of stable RCDT operation up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Due to possible evolutions affecting the RCDT, the duration of long term trend will be determined by the SM/CRS.

5.13 Component leakage (valve packing, pump seal, fitting leakage, etc.) from accessible sources may only be treated as Miscellaneous Identified leakage if the source has been identified AND the actual value of the leakage is obtained by a measurement taken at the start or during the data taking interval for the surveillance test. The leakage must be measured each time the OST is performed if it is to be credited towards Miscellaneous Identified RCS Leakage.

Each component leak must have an active Work Order.

5.14 This procedure has been reviewed and found to be not applicable as per the requirements of OPS-NGGC-1306, Reactivity Management.

6.0 SPECIAL TOOLS AND EQUIPMENT 6.1 Calibrated Stop Watch (If needed to collect Miscellaneous RCS Identified Leakage) 6.2 Graduated Container (If needed to collect Miscellaneous RCS Identified Leakage) 7.0 ACCEPTANCE CRITERIA 7.1 This test is acceptable if:

- Unidentified RCS Leakage Rate does NOT exceed 1 gpm

- Identified RCS Leakage Rate does NOT exceed 10 gpm

- Primary-to-Secondary leakage does NOT exceed 75 gpd through any one steam generator as determined by CP-014.

7.2 The reviewing and approving authorities may accept this test in accordance with provisions set forth in OMM-015, Operations Surveillance Testing.

OST-051 Rev. 45 Page 8 of 24

Section 8.1 Page 1 of 5 8.0 PROCEDURE INIT 8.1 RCS Leakage Rate Test 8.1.1 VERIFY RCS MAKEUP MODE in the AUTO position.

8.1.2 VERIFY RCS MAKEUP SYSTEM is ON.

8.1.3 IF desired, THEN PLACE LCV-1 15A, VCT/HLDP TK Dlv, in the VCT position.

NOTES: Whenever possible, use the ERFIS computer for data collection. This will improve accuracy and reduce the potential for human error.

The ERFIS on-screen historic information may be used to assist with data collection. This is especially helpful during a xenon transient or when in AOP-016, Excessive Primary Plant Leakage.

Measurement of leakage in Step 8.1 .4.c, and the calculation of Total Measured Leakage in Step 8.1 .4.d may be performed immediately prior to or at any time during the duration of this test.

The following step may be N/A if there is no active leakage issuing from components previously identified by work order.

8.1.4 IF there are any components that have known, active leakage, where the source is identified and can be treated as Miscellaneous Identified RCS Leakage or Known Non-RCPB Leakage per P&L 5.7 and P&L 5.13, THEN PERFORM the following on Attachment 10.5:

a. LIST the actively leaking component(s)

b. RECORD the Work Order number(s) for the component(s)

c. RECORD the measured leakage for the component(s)

d. CALCULATE the Total Measured Leakage Peer Check 8.1.5 RECORD the Initial Values for the parameters listed on Attachment 10.1.

OST-051 Rev. 45 Page 9 of 24

Section 8.1 Page 2 of 5 INIT 8.1.6 IF an automatic makeup occurs, THEN PERFORM the following:

1. VERIFY LCV-115A, VCT/HLDP TK Dlv, in the

(

AUTO position.

2. STOP this procedure AND NOTE reason in Comments section.

NOTES: When this procedure is being performed to satisfy ITS SR 3.4.13.1, the preferred duration is greater than or equal to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and the minimum duration 15 minutes.

When this procedure is being performed as directed by an AOP, there is not a minimum duration requirement.

8.1.7 WHEN at least 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months has elapsed, OR, IF required by Plant conditions to end this test, THEN PERFORM the following:

1. VERIFY RCS temperature is equal to initial RCS temperature recorded on Attachment 10.1.

2. RECORD the Final Values for the parameters listed on Attachment 10.1.

3. VERIFY LCV-1 15A, VCT/HLDP TK DIV, in the AUTO position.

NOTES: A decrease in VCT level represents plus (+) RCS leakage.

A decrease in Pressurizer level represents plus (÷) RCS leakage.

8.1.8 CALCULATE the Difference and Change in Volume for the parameters listed on Attachment 10.1.

8.1.9 PERFORM a peer check of the calculated values listed in Attachment 10.1.

OST-051 Rev. 45 Page 10 of 24

Section 8.1 Page 3 of 5 INIT NOTES: A plus (+) calculated Total RCS Leakage Rate represents plus (+) RCS leakage.

Leak-rates (in gpm) on Attachment 10.2 should be rounded to two decimal places.

8.1.10 On Attachment 10.2, PERFORM the following:

1. CALCULATE the Total RCS Leakage Rate.

2. CALCULATE the Identified RCS Leakage Rate.

3. CALCULATE the Unidentified RCS Leakage Rate.

4. PERFORM a peer check of the calculations performed on Attachment 10.2 8.1.11 IF unidentified RCS leakage is greater than 1.0 gpm OR the identified RCS leakage is greater than 10 gpm, THEN PERFORM the following:

1. CONSULT ITS LCO 3.4.13 for required actions.

2. CONSULT AP-030 for reporting requirements.

3. CONSULT EPCLA-01 for emergency action levels.

4. CONSULT AOP-016 for required actions.

8.1.12 IF RCS unidentified leakage is 0.05 gpm AND any valid R-24 monitor alarm OR any R-19 monitor indicates an increasing trend, THEN contact E&C Technician to perform Primary to Secondary Leakage Calculation for each steam generator in accordance with CP-014. (ITS LCD 3.4.13.d)

Primary to Secondary Leakage___________ gpd OST-051 Rev. 45 Page 1 1 of 24

Section 8.1 Page 4 of 5 IN IT 8.1.13 IF unidentified RCS leakage is equal to or greater than 0.03 gpm for 3 consecutive leak rate calculations, THEN perform the following:

1. Start an investigation immediately and inform plant staff.

2. IF not currently in progress, THEN start daily leak rate calculations.

NOTE: The RCS Leakage Monitoring Spreadsheet can be located at N :\NGGWEB\RN P\Departments\Operations\RCS Leakage Program or accessed from the OPS Tool Database 8.1.14 Update the RCS Leakage Monitoring Spreadsheet as follows:

1. LOG date and time.

2. ENTER RCS Identified and Unidentified RCS leakage.

3. PERFORM Peer Check of data entry fields prior to uploading any data.

4. CLICK UPLOAD DATA.

8.1.15 RECORD the following Unidentified Leak Rate data from the RCS Leakage Monitoring Spreadsheet:

1. Current Mean (ii) value

2. Current Sigma (a) value

3. Current [p + 2a] value

4. Current [p + 3o] value

5. 7 Day Rolling Average

6. Number of Consecutive Days greater than (p)

7. Last 3 Daily Unidentified Leak Rates OST-051 Rev. 45 Page 12 of 24

Section 8.1 Page 5 of 5 IN IT 8.1.16 Evaluate Unidentified Leakage against the Action Level Criteria Below:

Action Action Level Level Action Level Limit Description Exceeded (Circle One) 7-day rolling average of daily Unidentified RCS Tier One YES NO leak rates is greater than 0.1 gpm Action Level Nine consecutive daily unidentified RCS leakage values> mean (p) YES I NO Two consecutive daily Unidentified RCS leak Tier Two YES / NO rates are greater than 0.15 gpm Action Two of three consecutive daily Unidentified leak Level YES I NO rates greater than [p+2aJ One daily Unidentified RCS leak rate is greater Tier Three YES / NO than 0.3 gpm Action One daily Unidentified RCS leak rate is greater Level YES I NO than [p+3a]

8.1.17 IF any Unidentified RCS leakage Action Level (AL) is exceeded, THEN PERFORM the following:

1. REVIEW and implement the appropriate actions of Attachment 10.4, Action Level Response Guidelines while continuing with this procedure.

2. INITIATE an Action Plan lAW PLP-121 to document actions taken.

8.1.18 UPDATE leakage rate on Control Room status board.

8.1.19 IF Attachment 10.4, Action Level Response Guidelines was required, THEN ATTACH it to this OST when submitting to Records.

OST-051 Rev. 45 Page 13 of 24

INJI 9.0 RECORDS 9.1 Completed procedure, included completed partials shall be retained as a non permanent QA record 10.0 ATTACHMENTS 10.1 Leakage Evaluation Data Sheet 10.2 Leakage Evaluation Calculation Sheet 10.3 Level to Gallons Conversion Table 10.4 Action Level Response Guidelines 10.5 Components with Known Measured Leakage 10.6 Surveillance Test Procedure Certification and Review Form OST-051 Rev. 45 Page 14 of 24

I -

a ATTACHMENT 10.1 Page 1 of 2 LEAKAGE EVALUATION DATA SHEET REF ITEM VCT LVL PZR LVL RCS PZR ACCUM STEP ACCUM ACCUM RCS CHARGING TEMP TIME RELIEF A 8 C l5 A DRAIN PUMP LEAK (M TANK or T TANK OFF COLL.

or (1) (7)

LI-112 LI-I 003 TANK LI-460 Ll-470 TR-408 or or or (2) LIC-200 Tavg LI-922 LI-926 LI-930 (3)

<540°F TR-413 8.1.5 Initial Date/Time Values Date/Time in °F 7-% %

2-0gl) gal(2) 8.1.7.2 Final gal(3)

Date/Time Values Date/Time in % °F % % % I (7/3 gal(I) 8.1.8 Difference gal(2) gal(3)

(+1-) in % % % % gal gal Multiplier 23.99 min(4) 50.56 7 gal/% 7 gal/% 7 gal/%

gal/in gal/%

8.1.8 Change in Volume (gals) ) I Comments OST-051 Rev. 45 Page 15 of 24

C 0 ATTACHMENT 10.1 Page 2 of 2 (1) Use Curve Book, Curve 8.23 or Attachment 10.3, to convert PRT level into gallons OR mark as N/A if level did not increase.

(2) Use Curve Book, Curve 8.10, to convert RCDT level into gallons OR mark as N/A if level did not increase. To improve the accuracy of the Reactor Coolant Drain Tank (RCDT) level changes calculated during this procedure, a long term trend should be used for data collected from LI-I 003. A spreadsheet was developed to log RCDT levels that would provide a graph of the RCDT Trend. The file is located at V:\Operations\STA\RCDT Level. This graph or an ERFIS plot should be monitored for changes in inleakage rates into the RCDT. Duration of the long term RCDT trend should be any period of stable RCDT operation up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . (Actual duration of long term trend will be determined by the SM/CRS).

(3) Use Curve Book, Curve 8.22 or Attachment 10.3, to convert Charging Pump Leak-off Collection Tank level into gallons or mark as N/A if level did not increase.

(4) Minimum test duration of 15 minutes is required when performing this procedure to satisfy ITS SR 3.4.13.1.

(5) Circle the respective indicator/indication used. IF ERFIS is in service, THEN use it to obtain values.

IF ERFIS is not in service, THEN obtain the values from the respective RTGB indicators AND make a comment in the Comments section that RTGB indicators were used for the OST.

(6) An increase in SI Accumulator is (÷) RCS Leakage. IF the increase is due to SI Accumulators sluicing from one accumulator to another, THEN do not include the change in the identified RCS leakage rate. A decrease in SI Accumulator is (-) RCS leakage ONLY IF RCS pressure is less than SI Accumulator pressure.

(7) PZR RELIEF TANK Level Initial & Final should be collected from ERFIS using long term trend up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of Stable PRT Operation. An ERFIS plot should be monitored for changes in inleakage rates into the PRT. Duration of the long term PRT trend should be any period of stable PRT operation up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . (Actual duration of long term trend will be determined by the SM/CRS)

OST-051 Rev. 45 Page 16 of 24

ATTACHMENT 10.2 Page 1 of I LEAKAGE EVALUATION CALCULATION SHEET Identified RCS Leakage Rate PRT Volume Change gal Test Duration mm gpm SI ACC NB/C Volume Change gal Test Duration mm + gpm RCDT Volume Change gal Test Duration mm + gpm Leak-Off Coil Tk Volume Change gal Test Duration mm + gpm Miscellaneous Identified RCS Leakage Rate from Aft. 10.5

+ gpm Total Identified RCS Leakage Rate (MSPI) gpm Unidentified RCS Leakage Rate Total RCS Leakage Rate gpm Total Identified RCS Leakage Rate

- gpm Unidentified RCS Leakage Rate gpm OST-051 Rev. 45 Page 17 of 24

ATTACHMENT 10.3 Page 1 of I LEVEL TO GALLONS CONVERSION TABLE Charging Pump Leakoff Pressurizer Relief Tank Collection Tank Curve 8.22 Curve 8.23 Level Gallons Level Gallons Level Gallons Level Gallons Indicated Indicated Indicated Indicated 1 0.17 51 22.00 70.0 2 7075.00 75.1 7572.25 0.33 52 22.66 70.1 7084.75 3 75.2 7582.00 0.50 53 23.17 70.2 7094.50 4 75.3 7591.75 54 23.66 70.3 7104.25 75.4 5 55 7601.50 24.17 70.4 7114.00 75.5 7611.25 6 lii 56 24.66 70.5 7123.75 75.6 7621.00 7 57 25.33 70.6 7133.50 75.7 7630.75 8 58 25.84 70.7 7143.25 75.8 7640.50 9 2.00_ 59 26.33 70.8 7153.00 75.9 7650.25 10 2,33 60 26.84 70.9 7162.75 76.0 7660.00 11 2.66 61 27.51 71.0 7172.50 76.1 7669.75 12 3.00 62 28.00 71.1 7182.25 76.2 7679.50 13 3.33 63 28.50 71.2 7192,00 76,3 7689.25 14 3.66 64 29.00 71.3 7201.75 76.4 7699.00 15 4.00 65 29.33 71.4 16 7211.50 76.5 7708.75 4.33 66 30.17 71.5 7221.25 17 76.6 7718.50 4.6a 67 30.66 71.6 7231.00 18 76.7 7728.25 5.33 68 31.17 71.7 7240,75 19 76.8 7738.00 5.66 69 31.66 71.8 7250.50 20 76.9 7747.75 6.00 70 32.11 71.9 7260.25 21 6.50 71 .ZLP 7757.50 32.66 72,0 7270.00 .ZL1 7767.25 22 7.00 72 33.33 72.1 23 7279.75 IL? 7777.00 7.33 73 33.66 72.2 7289.50 24 7.84 74 fl 7786.75 34.33 72.3 7299.25 77.4 7796.50 25 8.33 75 34.6S 72.4 7309.00 77.5 106.25 26 8.83 76 35.17 72.5 7318.75 77.6 7816.00 27 9,33 77 35.66 72.6 7328.50 77.7 7825.75 28 9.84 78 36.00 72.7 7338.25 77.8 7835.50 29 10.33 79 36.50 72.8 7348.00 77.9 7845.25 30 10.83 80 36.84 72.9 7357.75 78.0 7855.00 31 11.33 81 37.33 73.0 7367.50 78.1 7864.75 32 11.84 82 37.66 73.1 7377.25 78.2 7874.50 33 12,33 83 38.00 73,2 7387.00 78.3 7884.25 34 13.00 84 38.50 73.3 35 7396.75 78.4 7894.00 13.49 85 38.83 73.4 7406.50 36 78.5 7903.75 14.00 86 39,17 73.5 7416.25 37 78.6 7913.50 14,66 87 39.66 73,6 7426.00 38 78.7 7923.25 15.18 88 40.00 73,7 7435.75 39 78.8 7933.00 15.66 89 40.33 73.8 7445.50 40 78.9 7942.75 16.17 90 40.50 73.9 7455.25 41 79.0 7952.50 16.66 91 40.84 74.0 7465.00 42 79.1 7962.25 17.00 92 41.00 74.1 7474.75 43 79.2 7972.00 17.66 93 41.33 74.2 7484.50 44 79.3 7981.75 18.33 94 41.66 74.3 7494.25 45 79.4 7991.50 18.83 95 41.83 74.4 7504.00 46 79.5 8001.25 19.33 96 41.84 74.5 7513.75 47 79.6 8011.00 20,00 97 42.33 74.6 7523.50 48 79.7 8020.75 20.50 98 42.66 74.7 7533.25 49 79.8 8030.50 21.00 99 42.83 74.8 7543.00 50 79.9 8040.25 21.50 100 43.0_p 74.9 7552,75 80.0 8050.00 75.0 7562.50 OST-051 Rev. 45 Page 18 of 24

ATTACHMENT 10.4 Page 1 of 4 ACTION LEVEL RESPONSE GUIDELINES DEFINITIONS: Daily means the daily average value which is the average of all valid measurements performed on a given calendar day.

MEAN (p) Average of the valid leak rates for a given period of time.

STANDARD DEVIATION (a) A measure of the degree of dispersion of the data from the mean value.

NOTE: Daily for below Action Levels should be interpreted as periodic if the ULR measurements are performed on less than a daily basis. That is, a periodic value is always a daily average value but is not evaluated every calendar day.

INIT Response Guidelines for Exceeding Tier One Action Levels

a. IF one 7-day rolling average of daily Unidentified RCS leak rates is greater than 0.1 gpm OR nine consecutive daily unidentified RCS leakage values> mean (ii), THEN PERFORM the following:

1) CONFIRM indication.

2) PERFORM a confirmatory leak rate calculation.

3) CHECK for abnormal trends on other leakage indicators.

4) FORWARD data to Engineering to evaluate trends.

5) INCREASE monitoring as recommended by Engineering.

6) INITIATE a condition report. NCR #

7) NOTIFY Operations Management OST-051 Rev. 45 Page 19 of 24

ATTACHMENT 10.4 Page 2 of 4 ACTION LEVEL RESPONSE GUIDELINES

2. Response Guidelines for Exceeding Tier Two Acti INIT on Levels

a. IF two consecutive daily Unidentified RCS leak rates are greater than 0.15 gpm OR two of three consecutive daily Unid entified leak rates greater than [p+2aJ, THEN PERFORM the follo wing:

1) VERIFY Tier One response guidelines have been performed.

2) COMMENCE a leak investigation as follows:

.a) REVIEW recent plant evolutions.

.b) EVALUATE changes in other leakage detection indications.

.c) INITIATE walkdowns of various portions of potential ly affected systems outside containment.

3) IDENTIFY the source of the increase in leakage as follows:

.a) CHECK any components OR flow paths recently changed or placed in service, shutdown, vented, drained, or filled.

.b) CHECK any maintenance activity that may have resulted in increasing leakage.

.c) CHECK any filters recently alternated OR changed for leakage from their vents or drains.

INSPECT filter housing for gaskets leakage.

CHECK seal injection filters AND reactor coolant filter for signs of leakage.

4) NOTIFY Operations Management OST-051 Rev. 45 Page 20 of 24

ATTACHMENT 10.4 Page 3 of 4 ACTION LEVEL RESPONSE GUIDELINES

3. Response Guidelines for Exceeding Tier Three Acti INIT on Levels

a. IF one daily Unidentified RCS leak rate is greater than 0.3 gpm OR

[p+3aJ, THEN PERFORM the following:

1) VERIFY Tier One AND Tier Two response guidelines have been performed.

2) IF increased leak rate is indicated inside containm ent, THEN PERFORM the following:

.a) BEGIN PLANNING for a containment entry.

NOTE: There is a single valve outside of containment to obta in this sample in pipe alley WD-1731A.

.b) NOTIFY E&RC to OBTAIN a containment sump sample (during pump out) AND analyze for activity and boron concentration lAW CP-003, (looking for a larger than expected boric acid concentration OR other unexpected chemicals).

E&RC NOTIFIED

.c) EVALUATE other systems for indications of leakage.

.d) OBTAIN a containment atmosphere sample for indications of RCS leakage.

OST-051 Rev. 45 Page 21 of 24

ATTACHMENT 10.4 Page 4 of 4 ACTION LEVEL RESPONSE GUIDELINES 3.0 (Continued) INIT Response Guidelines for Exceeding Tier Three Acti on Levels

3) IDENTIFY the source of the leak.

4) QUANTIFY the leakage.

5) INITIATE a plan to repair the leak.

6) MONITOR containment airborne radiation levels AND area radiation monitors.

7) SAMPLE containment atmosphere for indications of RCS leakage.

8) MONITOR other containment parameters (tempera ture, pressure, humidity, etc.).

9) IF the leak source is found AND isolated OR stop ped, THEN RE-PERFORM RCS leak rate calculation.

10) NOTIFY Operations Management OST-051 Rev. 45 Page 22 of 24

ATTACHMENT 10.5 Page 1 of 1 COMPONENTS WITH KNOWN MEASURED LEAKAGE NOTE: If leakage can NOT be collected in a suitable cont ainer to accurately measure in milliliters per minute (such as when leakage is in a high dose area but can be viewed by camera), this drops per minute conv ersion may be used. To convert drops per minute to gallons per minu te, multiply drops per minute by 132 x 10-5 (0.0000132). The drop counting meth od shall only be allowed if NO other means is available to measure leaka ge due to inaccessibility from a radiation dose or personnel safety standpoint base d on CRS/SM guidance.

To convert milliliters per minute to gallons per minute, multiply milliliters per minute by 2.64 x i0 4 (0.000264). This is the preferred method for calcu leakage. lating Individual component leakage should not be roun ded. Rounding should be completed in the Total Measured Leakage calcu lation to 2 significant digits, as this is what will be used by the Leak Rate prog ram.

Measured Measured D u ration Component Leakage Leakage Active Work Time (gpm) Volume Order Number 1 V-// oc /OCL. /1(1 M,A Z1( -

OfrH1 -f/AdoL

-x Total Measured Leakage A gpm OST-051 Rev. 45 Page 23 of 24

ATTACHMENT 10.6 Page 1 of I SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM uleJnscheduled (Circle one)

(If unscheduled, state reason for test and the page numbers included in partial test)

Test Performed By:

)1ame (Pin3

,e&. 1Y1/-t2R D+/-e Test Complete: Date: Time:

Test Satisfactory: Yes / No (Circle one)

Reviewed by:

Shift Technical Advisor Date Comments: (Required if results were unsatisfactory

)

Approved by:

Shift Manager Date OST-051 Rev. 45 Page 24 of 24

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Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 01000100905 Task

Title:

Calculate the Boron Addition JPM No.: 2011-2 NRC JPM RO Required Prior to Initiating a Natural A1-2 Circulation Cooldown to CSD K/A

Reference:

G2.1.25 3.9/4.2 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

The plant tripped from 50% RTP when a loss of off-site power occurred.

The crew is performing EPP-5, Natural Circulation Cooldown.

The TSC is NOT staffed.

Core Burnup is 11000 MWD/MTU

Boron Concentration is 600 PPM

Tavg is 54TF

Boric Acid Storage Tank A is in service, aligned to blend with level at 85%.

POWERTRAX is NOT available.

Task Standard: Boron addition and BAST level change calculated within stated standards.

Required Materials: Station Curve Book Straight Edge EPP-5, Step 11 General

References:

EPP-5, Natural Circulation Cooldown, Revision 15 2011-2 NRC JPM ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Station Curve Book, Revision 199 Handouts: EPP-5, Step 11 Initiating Cue: The CRS wants to initiate boration while necessary support personnel are reporting. You have been directed to determine the minimum required boron concentration for CSD (2OOF) and then calculate the boron addition necessary to achieve that boron concentration (with no allowance for PZR outsurge). In accordance with OP-30i, For large additions, ESTIMATE expected BAST level decrease for target boration.

Time Critical Task: NO Validation Time: 12 minutes 2011-2 NRC JPM ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 9 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Performance Step: I Determine minimum CSD Boron Concentration.

Standard: Determines Station Curve Book Curve 1.14 or Table 1.14 applies.

Examiners Note:

Comment:

Performance Step: 2 Determine minimum CSD Boron Concentration.

Standard: Reads no less than 1075 PPM and no more than 1100 PPM on Curve 1.14 or 1081 PPM from Table 1.14.

Examiners Note: The curve line falls between the 1050 PPM and the 1100 PPM line, allowing for a minor curve reading error since increments are 50 PPM.

Comment:

Performance Step: 3 Determine the boron concentration change required.

Standard: 1081 PPM600PPM481 PPM Examiners Note: 1075 PPM 600 PPM 475 PPM 1100 PPM -600 PPM500 PPM Comment:

2011-2 NRC JPM ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 9 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 4 Determine boration required.

Standard: Using Boron I Dilution Table 5.11 of the Station Curve Book, System Temperature of 547°F, calculated boric acid addition is 1195.9 gallons (1081 PPM)

Minimum - 1075 PPM, boration volume is 1180.8 gallons Maximum -1100 PPM, boration volume is i243.7 gallons Examiners Note:

Comment:

2011-2 NRC JPM RO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 9 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 5 For large additions, ESTIMATE expected BAST level decrease for target boration.

Standard: Utilizing Station Curve 8.18, determines final BAST level to be between 60 62.5%.

Examiners Note: Calculation on Curve 8.18 as follows:

GALLONS to % LEVEL = (GALLONS 1024)152.36

% LEVEL to GALLONS = (% LEVEL)(52.36) + 1024 BAST level of 85% = 5474.6 gallons Volume of boric acid to be added to the RCS = >1180.8 gallons and <1243.7 gallons.

5474.61195.9 = 4278.7 gallons which equates to a BAST level of 62.16%.

5474.6 1180.8 = 4293.8 gallons which equates to a BAST level of 62.45%.

5474.6 1243.7 = 4230.9 gallons which equates to a BAST level of 61.25%.

Examiners Note:

If candidate reads Curve 8.18 for level change:

5425 1195.9 = 4229.1 gallons which equates to a BAST level of 62%.

5425 1180.8

= 4244.2 gallons which equates to a BAST level of 62%.

5425 1243.7 = 4181.3 gallons which equates to a BAST level of 60%.

2011-2 NRC JPM RO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 9 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 6 OPTIONAL STEP: To be used if FIGURE S-3.1-3 (Curve Book 5.3), BORON ADDITION-COOLANT HOT is used for boration volume determination.

Determine boration required and ESTIMATE expected BAST level decrease for target boration.

Standard: Using FIGURE S-3.i-3 (Curve Book 5.3), BORON ADDITION-COOLANT HOT, determines boric acid addition of 1100 gallons (Range of 1068 to 1131 gallons.).

Final BAST level is 63-64.5%.

Examiners Note: 4325 gallons which equates to a BAST level of 54251100 =

63%.

5475 1100 = 4375 gallons which equates to a BAST level of 64%.

5425 1068 = 4357 gallons which equates to a BAST level of 64%.

5425 1131 = 4294 gallons which equates to a BAST level of 63%.

5475 1068

= 4407 gallons which equates to a BAST level of 64.5%.

5475 1131 = 4344 gallons which equates to a BAST level of 63%.

Examiners Cue: . . .

If candidate determines boration requirement using FIGURE S-3.1.3, question the candidate as to whether there are alternative means of determining the required boration volume (See JPM Performance Steps). Allow the candidate the opportunity to re-calculate the boration using the previous JPM steps.

Comment:

2011-2 NRCJPM ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 9 Form ES-C-I PERFORMANCE INFORMATION END OF TASK Terminating Cue: When the BAST Level estimate is complete, inform Candidate that the evaluation on this JPM is complete.

STOP TIME:

2011-2 NRC JPM ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 9 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM RO Ai-2 Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM ROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 9 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

The plant tripped from 50% RTP when a loss of off-site power occurred.

The crew is performing EPP-5, Natural Circulation Cooldown.

The TSC is NOT staffed.

Core Burnup is 11000 MWD/MTU

Boron Concentration is 600 PPM

Tavg is 54TF

Boric Acid Storage Tank A is in service, aligned to blend with level at 85%.

POWERTRAX is NOT available.

INITIATING CUE: The CRS wants to initiate boration while necessary support personnel are reporting. You have been directed to determine the required boron concentration for CSD (200F) and then calculate the boron addition necessary to achieve that boron concentration (with no allowance for PZR outsurge). In accordance with OP 301, For large additions, ESTIMATE expected BAST level decrease for target boration.

2011-2 NRC JPM ROA1-2 NUREG 1021, Revision 9, Supplement i

Appendix C Page 9 of 9 Form ES-C-I JPM CUE SHEET INITIAL CONDITIONS:

The plant tripped from 50% RTP when a loss of off-site power occurred.

The crew is performing EPP-5, Natural Circulation Cooldown.

The TSC is NOT staffed.

Core Burnup is 11000 MWD/MTU

Boron Concentration is 600 PPM

Tavg is 54TF

Boric Acid Storage Tank A is in service, aligned to blend with level at 85%.

POWERTRAX is NOT available.

INITIATING CUE: The CRS wants to initiate boration while necessary support personnel are reporting. You have been directed to determine the required boron concentration for CSD (200F) and then calculate the boron addition necessary to achieve that boron concentration (with no allowance for PZR outsurge). In accordance with OP 301, For large additions, ESTIMATE expected BAST level decrease for target boration.

2011-2 NRC JPM RO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.:

Task

Title:

Perform Section 8.2.3 of OST-020, JPM No.: 2011-2 NRC JPM RO Shiftly Surveillances A2 K/A

Reference:

G2.2.37 3.6 I 4.6 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

Task Standard: Identify all out of specification readings.

Required Materials: OST-020 General

References:

OST-020 Shiftly Surveillances, Revision 41 Handouts: OST-020 Initiating Cue: You have relieved the OAC on the 07-1 900 watch due to a sudden illness. He was performing but unable to complete OST-020, Shiftly Surveillances. Perform Section 8.2.3, evaluate the acceptability of the instrument readings and document any unsatisfactory conditions in the comments section of Attachment 10.1.

Time Critical Task: NO Validation Time: 15 minutes 2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 2 of 9 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Examiners Cue: Provide OST-020 Cover Page through Section 7.0 and Section 8.2.3.

Performance Step: I Review procedure OST-020.

Standard: Reviews Precautions and Limitations and remainder of handout.

Examiners Note:

Comment:

Performance Step: 2 IF MODE i, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.1)

1. PZR Level (Channels LI-459A, 460 and 461)

Standard: Candidate compares the channel readings and determines that all channels are within 5% for PZR level.

Examiners Note:

Comment:

2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 9 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 3 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.2)

2. PZR Pressure (Channels P1-455, 456 and 457)

Standard: Candidate compares the channel readings and determines that channel P1-455 is outside of the tolerance of 40 psig from the other 2 channels.

Examiners Note:

Comment:

Performance Step: 4 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.3)

SIG Pressure for A SIG (Channels P 1-474, 475 and 476)

SIG Pressure for B SIG (Channels P1-484, 485 and 486)

S/G Pressure for C S/G (Channels P1-494, 495 and 496)

Standard: Candidate compares the channel readings and determines that channel P 1-484 is outside of the tolerance of 70 psig from the other 2 channels for SIG B.

Examiners Note:

Comment:

2011-2 NRC JPM RO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 9 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 5 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.4)

S/G Level for A SIG (Channels LI-474, 475 and 476)

S/G Level for B SIG (Channels Ll-484, 485 and 486)

SIG Level for C SIG (Channels Ll-494, 495 and 496)

Standard: Candidate compares the channel readings and determines that channel LI-475 is outside of the tolerance of 5% from the other 2 channels for SIG A.

Examiners Note:

Comment:

Performance Step: 6 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.5)

Steam Header Pressure (Channels Pl-464A, 466 and 468)

Standard: Candidate compares the channel readings and determines all of the Steam Header pressure channels are within the tolerance of 70 psig.

Examiners Note:

Comment:

2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 9 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 7 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.6)

S/G Steam Flows for SIG A (Channels FI-474 and 475)

S/G Steam Flows for S/G B (Channels Fl-484 and 485)

SIG Steam Flows for SIG C (Channels Fl-494 and 495)

Standard: Candidate compares the channel readings and determines all of the Steam Flow channels are within tolerance.

Examiners Note:

Comment:

Performance Step: 8 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.7)

Tavg (Channels TI-412D, 422D and 432D)

Standard: Candidate compares the channel readings and determines that channel Tl-432D is outside of the tolerance of 4°F from the other channels for Tavg.

Examiners Note:

Comment:

2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 9 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 9 IF MODE 1 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.8)

SI Accumulator A Level (LI-920 and 922)

SI Accumulator B Level (Ll-924 and 926)

SI Accumulator C Level (LI-928 and 930)

Standard: Candidate compares the channel readings and determines all of the SI Accumulator level channels are within the tolerance of 5%.

Examiners Note:

Comment:

Performance Step: 10 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.9)

SI Accumulator A Pressure (P1-921 and 923)

SI Accumulator B Pressure (P1-925 and 927)

SI Accumulator C Pressure (P1-929 and 931)

Standard: Candidate compares the channel readings and determines all of the SI Accumulator pressure channels are within the tolerance of 40 psig.

Examiners Note:

Comment:

2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 9 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Terminating Cue: When the instrument readings have been evaluated and comments made for any out of spec readings, the evaluation on this JPM is complete.

STOP TIME:

2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 9 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM RO A2 Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentalion:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 9 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

INITIATING CUE: You have relieved the QAC on the 07-i 900 watch due to a sudden illness. He was performing but unable to complete OST 020, Shiftly Surveillances. Perform Section 8.2.3, evaluate the acceptability of the instrument readings and document any unsatisfactory conditions in the comments section of Attachment 10.1.

2011-2 NRC JPM ROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 9 Form ES-C-I JPM CUE SHEET INITIAL CONDITIONS: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

INITIATING CUE: You have relieved the OAC on the 07-1 900 watch due to a sudden illness. He was performing but unable to complete OST 020, Shiftly Surveillances. Perform Section 8.2.3, evaluate the acceptability of the instrument readings and document any unsatisfactory conditions in the comments section of Attachment 10.1.

2011-2 NRC JPM RO A2 NUREG 1021, Revision 9, Supplement 1

C Continuous Progress Energy Use H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 PLANT OPERATING MANUAL VOLUME 3 PART 9 OST-020 SHIFTL Y SURVEILLANCES REVISION 41 Rev. 41 Page 1 of 54 OST-020

SUMMARY

OF CHANGES PRR 00453883 OST-020, Rev. 41 STEP REVISION COMMENTS ed the step 8.7.2.4.A Removed reference to the local wind up chart recorder. Chang instrument to a wording from CHECK a value from a calibrated temperature instrument.

CHECK local temperature using a calibrated temperature recorder. Changed the step New NOTE Removed reference to the local wind up chart wording three instruments do not take temper atures to two instruments may prior to step not take temperatures.

8.7.2.4.B 8.7.2.4.B Removed reference to the local wind up chart recorder.

ed the step 8.7.2.8A Removed reference to the local wind up chart recorder. Chang instrument to a wording from CHECK a value from a calibrated temperature ature instrum ent.

CHECK local temperature using a calibrated temper recorder. Changed the step New NOTE Removed reference to the local wind up chart instruments may prior to wording three instruments do not take temperatures to two step not take temperatures.

8.7.2.8.B 8.7.2.8B Removed reference to the local wind up chart recorder.

Rev. 41 Page 2 of 54 OST-020

TABLE OF CONTENTS PAGE SECTION 4

1.0 PURPOSE 4

2.0 REFERENCES

6 3.0 RESPONSIBILITES 6

4.0 PREREQUISiTES 6

5.0 PRECAUTIONS AND LIMITATIONS 8

6.0 SPECIAL TOOLS AND EQUIPMENT 8

7.0 ACCEPTANCE CRITERIA 9

8.0 PROCEDURE 9 8.1 Reactivity Control Systems 11 8.2 Instrumentation 28 8.3 Reactor Coolant System 41 8.4 Emergency Core Cooling Systems 45 8.5 Containment Systems 46 8.6 Plant Systems 47 8.7 Other 52 9.0 RECORDS 52 10.0 ATTACHMENTS AND REVIEW 10.1 SURVEILLANCE TEST PROCEDURE CERTIFICATION 53 FORM (Shift 07-19)

AND REVIEW 10.2 SURVEILLANCE TEST PROCEDURE CERTIFICATION 54 FORM (Shift 19-07)

Rev. 41 Page 3 of 54 OST-020

1.0 PURPOSE shiftly 1.1 To provide instructions for performing ITS, TRM or ODCM required REFER TO OST-0 20-1 for surveillances during Modes 1 through 5, AND ted fuel assemb lies, DSC required shiftly surveillances during movement of irradia loading, Mode 6 and defueled operation.

306 AND THIS PROCEDURE HAS BEEN SCREENED lAW OPS-NGGC-1 TIVIT Y MANA GEMENT PROGRAM DETERMINED NOT APPLICABLE TO THE REAC (PRR 00374090)

2.0 REFERENCES

2.1 Improved Technical Specifications (ITS)

DSC Loading, 2.2 OST-020-1, Shiftly Surveillances (Irradiated Fuel Movement, Mode 6 and Defueled Operation) 2.3 OMM-015, Operations Surveillance Testing 2.4 OMM-001-11, Logkeeping 2.5 OP-006, Pressurizer PORV Pneumatic System/LTOPP 2.6 OMM-024, Rod Position Channel Check 2.7 OP-920, Radiation Monitoring System 2.8 PLP-100, Technical Requirements Manual (TRM) 2.9 ODCM, Offsite Dose Calculation Manual 2.10 EST-047, Reactor Coolant Flow Test Low Power Levels.

2.11 ESR 97-00601, Channel Check Tolerances for Steam Flow at Rev. 41 Page 4 of 54 OST-020

2.12 ESR 97-00611, Rod Position Indication Drift ation 2.13 RNP-I/INST-1040, Revision 1, Main Steam Accuracy and Scaling Calcul 2.14 RNP-l/INST-1128, Revision 0, FT-424 Error/Uncertainty Calculation 2.15 8S19-P-101, Station Blackout Coping Analysis Report 2.16 CR 97-02328, SR 3.1.6.2 Documentation 2.17 GP-010, Refueling 2.18 ESR 99-00220, Alternate method of determining Seal Injection flow 2.19 EC 47162, Set-Points, Uncertainty CaIc change for Appendix K Uprate 2.20 LDCR 03-0002, Proposed change to LCO 3.1.7, Required Action A.1 2.21 NCR 188409, New Containment Analysis from Westinghouse 2.22 NCR290724, Black Creek Temperature Exceedance [CAPRI (P-500 &

2.23 RNP-I/INST-1 127, LTQP Loop Uncertainty and Sealing Calculation 501)

Rev. 41 Page 5 of 54 OST-020

3.0 RESPONSIBILITES and approval 3.1 Operations personnel are responsible for the performance, review of this test.

wind up chart 3.2 Unit one Chemistry personnel is responsible for checking the local recorder indication as required by plant procedure.

Control Board 3.3 Unit one control room personnel is responsible for providing the Indication for Discharge Canal Weir temperature.

ilT 4.0 PREREQUISITES 4.1 This revision has been verified to be the latest revision available.

Date 4.2 The Shift Manager has given permission to conduct this test.

4.3 RECORD plant mode which shiftly checks are being performed.

(07-1 9)MODE (1 9-07)MODE 5.0 PRECAUTIONS AND LIMITATIONS noted in the 5.1 Any steps not applicable shall be marked N/A and the reason(s)

COMMENTS section of Attachment 10.1 or 10.2.

determined not 5.2 This procedure has been screened lAW PLP-037 criteria and applicable to PLP-037.

unless specified.

5.3 Steps within this procedure may be performed in any sequence, 5.4 Steps may be done concurrently between watchstations.

Rev. 41 Page 6 of 54 OST-020

turbine 5.5 The following guidance does NOT apply to Steam Flow instruments when NOT load is less than 20% AND only applies to RTGB instrumentation. It is intended to apply to instrumentation of different types sensing the same red parameter (i.e., direct reading local pressure gauge shall NOT be compa against a pressure transmitter driving a remote meter): (CR 95-02700) 5.5.1 A deviation greater than 5% of full scale is used as the QOS limit. The instrument shall be declared QOS.

s in 5.6 Steam Flow loops are pressure compensated to account for density change calibra tion of the the steam that occur from low-load to full-load operation. The result, the loops are set up for optimum performance at 100% of rated flow. As a operable but performance of the loops at low flows is not as accurate, and can be ation, the follow ing should may not meet the 5% tolerance. Based on this inform ents: (CR 95-be used for channel check of the redundant Steam Flow instrum 02700) 5.6.1 IF Turbine load is less than or equal to 20%, THEN Steam Flow should be greater than 90% of indicated Feed Flow.

AND The tolerance between redundant Steam Flows should be within ph 0.4x p

6 lO . (ESR 97-00601) n 5.6.2 IF Turbine load is greater than 20%, THEN the tolerance betwee redundant Steam Flow instruments should be within 5%.

20%

5.6.3 If it appears that the 5% tolerance will not be met prior to exceeding Turbine load, THEN Engineering should be contacted to evalua te the specific situation.

unavailable 5.7 A channel check can be performed when a redundant channel is the channe l for unexplained (OOS). The qualitative check includes observation of s in power changes that are not attributable to known activities such as change unexplained level, filling, draining, heatup, cooldown, etc. Erratic behavior or condit ions that would warrant changes in the channel indication would be M/OD CM require d actions.

declaring the channel QOS and applying the ITSITR Rev. 41 Page 7 of 54 OST-020

6.0 SPECIAL TOOLS AND EQUIPMENT 6.1 IF NEEDED, THEN VERIFY the following test equipment calibration is current AND RECORD the test equipment identification below:

Equipment Identification INIT Calibrated Thermometer 7.0 ACCEPTANCE CRITERIA 7.1 All steps for the applicable Mode have been completed.

7.2 Performance of the surveillance satisfies the ITS, TRM and ODCM requirements and the OST should be considered SAT. IF the stated condition(s) is not met, THEN the applicable Action Statement is required to be entered.

7.3 The reviewing and approving authorities may accept this test lAW provisions set forth in OMM-015.

Rev. 41 Page 8 of 54 OST-020

Section 8.1 Page 1 of 2 8.0 PROCEDURE !tiI iiI 07-19 19-07 8.1 Reactivity Control Systems 8.1.1 IF MODE 1 OR 2 shiftly checks are required, THEN PERFORM the following:

1. VERIFY Individual Rod Positions are within alignment limits. (ITS SR 3.1.4.1)

2. VERIFY each Shutdown Bank is within the limits specified in the COLR. (ITS SR 3.1.5.1)

NOTE: When the Rod Insertion Limit monitor (APP-005-C5) is inoperable, ITS SR limits 3.1.6.2 requires the Control Bank position to be verified above the insertion 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereaf ter. This can be specified in the COLR once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months referen cing this performed by making an entry in the COs narrative log every SR number.

n indication A WR should be initiated when comparisons between Analog Rod Positio and bank demand position indication approach 7.5 inches.

3. VERIFY each Control Bank position is above the insertion limits specified in the COLR.

(ITS SR 3.1.6.2)

4. VERIFY Sequence and Overlap Limits specified in the COLR are met for Control Banks not fully withdrawn from the core. (ITS SR 3.1.6.3)

Rev. 41 Page 9 of 54 OST-020

Section 8.1 Page 2 of 2 8.1.1 (Continued) 1.N1I illI 07-19 19-07

5. For bank demand position at or above 200 steps, PERFORM CHANNEL CHECK by comparing Analog Rod Position indication and bank demand position indication. (The individual rod position indication (RPI) shall be within +/-15 inches of the bank demand position)(ITS SR 3.1.7.1)

NOTE: OMM-024, Rod Position Channel Check, provides applicable actions when ERFIS is inoperable.

The use of ERFIS is an acceptable alternate method for determining ARPI System ing Operability lAW Improved Tech Specs if the RTGB RPI indicators are not indicat

) are trackin g closely , and properly. In cases where both indications (RPI and ERFIS ion still within one of the indications is outside the required limits with the other indicat taken the limits, ERFIS should be considered the most accurate indication and actions If ERFIS readou t is used to replace the should be based on the ERFIS indication. the al access ible to the Reacto r RPI indicators, it shall be continuously displayed on a termin Operator.

(ESR 97-00611)

Position A WR should be initiated when comparisons between ERFIS Individual Rod indication and bank demand position indication approa ch 7.5 inches .

6. For bank demand position at or above 200 steps, PERFORM CHANNEL CHECK by comparing ERFIS Individual Rod Position indication and bank demand position indication. (The ERFIS individual rod position indication shall be within +/-15 inches of the bank demand position)

Rev. 41 Page 10 of 54 OST-020

Section 8.2 Page 1 of 17 INIT INIT 07-19 19-07 8.2 Instrumentation 8.2.1 IF MODE 1 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following:

NOTE: The following check is to determine the deviation between the highest and lowest channel of redundant indicators for the same parameter. The redundant than indicators to be compared are grouped in blocks. If the actual deviation is greater the maximum allowed deviation as shown (deviat ion of 5% of the full range of the indicators movement), it is unacceptable.

1. RCS Flow (ITS SR 3.3.1.1, Table 3.3.1-1 Item 9.a and 9.b)

F INSTRUMENT INSTRUMENT MAXIMUM j CALCULATION NUMBER

_j____ ______________

DEVIATION_

[ RANGE RNP-I/INST-1036 FI-414 0-120% 6%

FI-4 15 FI-4 16 FI-424 0-120% 6% RNP-I/INST-1036 FI-425 FI-426 FI-434 0-120% 6% RNP-I/I NST-1 036 F 1-4 35 FI-436 Rev. 41 Page 11 of 54 OST-020

Section 8.2 Page 2 of 17 8.2.1 (Continued) INIT INIT 07-19 19-07

2. Turbine Impulse Pressure (ITS SR 3.3.1.1, Table 3.3.1-1 Item 17.e)

INSTRUMEN INSTRUMENT MAXIMUM J CALCULATION NUMBER T RANGE DEVIATION L P1-446 0-900 psi 9 45 psig RNP-I/INST-1045 P1-447 8.2.2 IF MODE 1 OR 2 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following:

NOTE: The following check is to determine the deviation between the highest and ant lowest channel of redundant indicators for the same parameter. The redund deviati on is greater than indicators to be compared are grouped in blocks. If the actual range of the the maximum allowed deviation as shown (deviation of 5% of the full l power), it is indicators movement, except for S/G Feed Flow when <10% rated therma unacceptable. (ESR 97-00601)

1. Overtemperature AT Setpoint (ITS SR 3.3.1.1, Table 3.3.1-1 Item 5)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION NUMBER RANGE DEVIATION TI-412C WCAP 11889 TI-422C 0-75°F 4°F TI-432C

2. Overpower AT Setpoint (ITS SR 3.3.1.1, Table 3.3.1-1 Item 6)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION NUMBER RANGE DEVIATION TI-412B WCAP 11889 TI-422B 0-75°F 4°F TI-432B Rev. 41 Page 12 of 54 OST-020

Section 8.2 Page 3 of 17 8.2.2 (Continued) INIT INIT 07-19 19-07

3. Loop Protection zT (ITS SR 3.3.1.1, Table 3.3.1-1 Item 5 and 6)

INSTRUMEN INSTRUMENT RANGE MAXIMUM DEVIATION

[

j CALCULATION NUMBER T

TI-412A WCAP 11889 TI-422A 0-75°F 4°F TI-432A

4. SIG Feed Flow (ITS SR 3.3.1.1, Table 3.3.1-1 Item 14)

(ESR 97-00601)

IF 10% rated thermal power, THEN check the following:

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER FI-476 6 pph 0-4x10 6 ph 0.2xlO p RNP-I/INST-1041 FI-477 FI-486 0-4x1 06 pph pph 0.2x1 O 6 RNP-I/INST-1 041 FI-487 FI-496 6 pph 0-4x10 6 ph 0.2xlO p RNP-I/INST-1041 FI-497 IF <10% rated thermal power, THEN check the following:

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER FI-476 0-4x1 06 pph pph 0.4x1 O 6 RNP-I/I NST-1 041 FI-477 FI-486 0-4x1 06 pph pph 0.4x1 O 6 RNP-I/I NST-1 041 FI-487 FI-496 0-4x1 06 pph pph 0.4x1 O 6 RNP-I/I NST-1 041 FI-497 OST-020 Rev. 41 Page 13 of 54

Section 8.2 Page 4 of 17 8.2.2 (Continued) INIT INIT 07-19 19-07 NOTE: Source Range Neutron Flux check is applicable in MODE 2.

ination Per Calculations RN P-I/INST-I 134, RN P-I/INST -1135, and Engineering determ from NCR 00268640, the following Channel Check Acceptance Criteri a has been

, and deemed appropriate, for the Reactor Protection Source Range, Intermediate Range Power Range:

Power Range (N-41, N-42, N-43 and N-44): The acceptable deviation for the power range indication SHALL be within 2% power.

Intermediate Range: The logarithmic value of the lowest indication subtracted from the logarithmic value of the highest indication SHALL be 178.

Source Range: The logarithmic value of the lowest indication subtracted from the logarithmic value of the highest indication SHALL be 1 .48.

digital Due to the difficulty in reading a logarithmic meter with a fluctuating signal, the el Check s indication from ERFIS or NR-45 should be used to perform the Chann whenever possible.

Control The LOG function of an available calculator or the scientific calculator on the Room PC may be used to determine the logarithmic values. (NCR 268640)

5. Power Range Neutron Flux (ITS SR 3.3.1.1, Table 3.3.1-1 Item 2.a and 2.b):

a. PERFORM the following:

RECORD NI-41 indication % Power RECORD NI-42 indication % Power RECORD NI-43 indication % Power RECORD Nl-44 indication % Power Rev. 41 Page 14 of 54 OST-020

Section 8.2 Page 5 of 17 82.2.5 (Continued) INII INJI 07-19 19-07

b. CALCULATE maximum deviation:

Recorded (highest) minus Recorded (lowest) equals

c. PEER CHECK calculation.

d. DOCUMENT results (within 2% power):

SAT/UNSAT (Circle One)

6. PERFORM the following:

RECORD Nl-41 indication._______ % Power RECORD NI-42 indication._______ % Power RECORD Nl-43 indication % Power RECORD Nl-44 indication % Power

a. CALCULATE maximum deviation Recorded (highest) minus Recorded (lowest) equals

b. PEER CHECK calculation.

c. DOCUMENT results (within 2% power):

SAT I UNSAT (Circle One)

OST-020 Rev. 41 Page 15 of 54

Section 8.2 Page 6 of 17 8.2.2 (Continued) INIT INIT 07-19 19-07

7. Intermediate Range Neutron Flux (ITS SR 3.3.1.1, Table 3.3.1-1 Item 3)

a. RECORD Nl-35 indication.

b. RECORD N-36 indication.

c. CALCULATE deviation:

LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results ( 1.78). SAT! UNSAT (Circle one)

OST-020 Rev. 41 Page 16 of 54

Section 8.2 Page 7 of 17 8.2.2 (Continued) INIT INIT 07-19 19-07

8. Intermediate Range Neutron Flux (ITS SR 3.3.1.1, Table 3.3.1-1 Item 3)

a. RECORD NI-35 indication.

b. RECORD N-36 indication.

c. CALCULATE deviation:

LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results ( 1.78). SAT / UNSAT (Circle one)

9. IF required, THEN perform Source Range Neutron Flux check (if below P-6 Interlock)

(ITS SR 3.3.1.1, Table 3.3.1-1 Item 4)

a. RECORD Nl-31 indication.

b. RECORD N-32 indication.

c. CALCULATE deviation:

LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results ( 1.48). SAT / UNSAT (Circle one)

10. IF required, THEN perform Source Range Neutron Flux check (if below P-6 Interlock)

(ITS SR 3.3.1.1, Table 3.3.1-1 Item 4)

a. RECORD NI-31 indication.

b. RECORD N-32 indication.

OST-020 Rev. 41 Page 17 of 54

Section 8.2 Page 8 of 17 8.2.2.10 (Continued) NIT INIT 07-19 19-07

c. CALCULATE deviation: LOG (highest) minus LOG (lowest) equals:

d. PEERCHECKcalculation.

e. DOCUMENT results ( 1.48). SAT / UNSAT (Circle one 8.2.3 IF MODE 1, 2, OR 3 shittly checks are required, THEN PERFORM CHANNEL CHECK for the following:

NOTE: The following check is to determine the deviation between the highest and lowest channel of redundant indicators for the same parameter. The redundant indicators to be compared are grouped in blocks. If the actual deviation is greater than the maximum allowed deviation as shown (deviation of 5% of the full range of the indicators movement, except for S/G Steam Flow when <20% rated thermal power), it is unacceptable. (ESR 97-00601)

1. PZR Level (ITS SR 3.3.1.1, Table 3.3.1-1 Item 8 and ITS SR 3.3.3.1, Table 3.3.3-1 Item 12)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER LI-459A RNP-I/INST-1060 LI-460 0-100% 5%

LI-461 OST-020 Rev. 41 Page 18 of 54

Section 8.2 Page 9 of 17 INIT INIT 8.2.3 (Continued) 07-19 19-07

2. PZR Pressure IF Pressurizer Pressure is outside the indicating range due to normal plant conditions, THEN mark N/A.

(ITS SR 3.3.1.1, Table 3.3.1-1 Item 7.a, 7.b and ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.d and 6.a)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION NUMBER RANGE DEVIATION P1-455 1 RNP-I/INST-1042 P1-456 1700-2500 psig I 40 psig P1-457 j________________

3. S/G Pressure (ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.e, 1.g and 4.e, ITS SR 3.3.3.1, Table 3.3.3-1 Item 20) 1 INSTR UMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER P1-474 RN P-I/INST-i 072 P1-475 0-1400 psig 70 psig P1-476 P1-484 RNP-I/INST-1072 P 1-485 0-1400 psig 70 psig P1-486 P1-494 RNP-I/INST-1072 P1-495 0-1400 psig 70 psig P1-496 Rev. 41 Page 19 of 54 OST-020

Section 8.2 Page 10 of 17 8.2.3 (Continued) INIT INIT 07-19 19-07

4. SIG Level (ITS SR 3.3.1.1, Table 3.3.1-1 Item 13 and 14, ITS SR 3.3.3.1, Table 3.3.3-1 Item 13, ITS SR 3.3.8.1, Table 3.3.8-1 Item 1)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER LI-474 RNP-IIINST-1070 LI-475 0-100% 5%

LI-476 LI-484 RNP-I/INST-1070 LI-485 0-100% 5%

LI-486 LI-494 RNP-I/IN ST-i 070 LI-495 0-100% 5%

LI-496

5. Steam Header Pressure (ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.e)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER PI-464A RNP-I/INST-1050 P1-466 0-1400 psig 70 psig P1-468 OST-020 Rev. 41 Page 20 of 54

Section 8.2 Page 11 of 17 8.2.3 (Continued) INIT INIT 07-19 19-07

6. SIG Steam Flow (ITS SR 3.3.1.1, Table 3.3.1-1 Item 14 and ITS SR 3.3.2.1, Table 3.3.2-1 Item if, 1.g, 4.d and 4.e) (ESR 97-00601)

IF 20% rated thermal power, THEN check the following:

INSTRUMENT I INSTRUMENT RANGE 1 MAXIMUM DEVIATION CALCULATION I NUMBER FI-474 0-4x 1 6

pph pph 0.2x1 O 6 RNP-I1INST-1 040 FI-475 FI-484 6 pph 0-4x10 6 ph 0.2xlO p RNP-I/INST-1040 FI-485 FI-494 6 pph 0-4x10 6 ph 0.2xlO p RNP-I/INST-1040 FI-495 IF <20% rated thermal power, THEN check the following:

INSTRUMENT INSTRUMENT RANGE MAXIMUM DEVIATION FI-474 6 pph 0-4x10 pph 6

0.4xlO FI-475 between the following combinations:

Fl-474 AND FI-475

Fl 474 AND FI-477

Fl_475_AND_Fl-476 F 1-484 0-4x1 06 pph pph 0.4x1 O 6

FI-485 between the following combinations:

Fl-484 AND Fl-485

Fl 484 AND Fl-487

Fl_485_AND_Fl-486 Fl-494 6 pph 0-4x10 pph 6

0.4xlO Fl-495 between the following combinations:

FI-494 AND Fl-495

Fl 494 AND Fl-497

FI 495 AND FI-496 The Steam Flow Channel is checked against the corresponding Feed Flow channel for acceptance.

OST-020 Rev. 41 Page 21 of 54

Section 8.2 Page 12 of 17 8.2.3 (Continued) INIT INIT 07-19 19-07

7. Tavg IF Tavg is outside the indicating range due to normal plant conditions, THEN mark N/A.

(ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.f, 4.d and 6.b)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER TI-412D WCAP 11889 TI-422D 540-615°F 4°F TI-432D

8. SI Accumulator Level (TRMS TR 4.2.1)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER LI-920 0-100% 5% RNP-I/INST-1 052 LI-922 LI-924 0-100% 5% RNP-I/INST-1052 LI-926 LI-928 0-100% 5% RNP-I/INST-1 052 LI-930

9. SI Accumulator Pressure (TRMS TR 4.2.1)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER P1-921 0-800 psig 40 psig RNP-I/INST-1036 P1-923 P1-925 0-800 psig 40 psig RNP-I/INST-1036 P1-927 P1-929 0-800 psig 40 psig RNP-I/INST-1036 P 1-93 1 OST-020 Rev. 41 Page 22 of 54

Section 8.2 Page 13 of 17 8.2 (Continued) INIT INIT 07-19 19-07 8.2.4 IF MODE 1, 2, 3 OR 4 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following:

NOTE: The following check is to determine the deviation between the highest and lowest channel of redundant indicators for the same parameter. The redundant indicators to be compared are grouped in blocks. If the actual deviation is greater than the maximum allowed deviation as shown (deviation of 5% of the full range of the indicators movement), it is unacceptable.

1. CV Pressure (ITS SR 3.3.2.1, Table 3.3.2-1 Item ic, 2.c, 3.b.3 and 4.c)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER PI-950A RNP-I/INST-1044 P1-95 1 P1-952 -5 75 psig

- 4 psi 9

P1-953 P1-954 P1-955 OST-020 Rev. 41 Page 23 of 54

Section 8.2 Page 14 of 17 8.2.4 (Continued) 1.NJI INII 07-19 19-07

2. PZR Pressure IF RCS pressure is outside the indicating range due to normal plant conditions, THEN mark N/A.

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER P1-500 200-600psig 20 psig RNP-I/INST-1127 PI-501A

1) IF RCS pressure is outside the indicating range due to normal plant conditions, THEN mark N/A.

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER P1-444 1700-2500 psig 40 psig RNP-I/INST-1042 P1-445 NOTE: The following instrument does not have a redundant indicator; therefore Maximum Deviation values are not provided.

OP-920, Radiation Monitoring System, provides instructions for performing radiation monitor channel checks.

3. Control Room Radiation Monitor R (ITS SR 3.3.7.1, Table 3.3.7-1 Item 2)

OST-020 Rev. 41 Page 24 of 54

Section 8.2 Page 15 of 17 8.2 (Continued)

NOTE: Per Calculation RNP-I/INST-1134 and Engineering determination from NCR 00268640, the following Channel Check Acceptance Criteria has been deemed appropriate for the Reactor Protection Source Range Instrumentation:

Source Range: The logarithmic value of the lowest indication subtracted from the logarithmic value of the highest indication SHALL be 1 .48.

Due to the difficulty in reading a logarithmic meter with a fluctuating signal, the digital indication from ERFIS or NR-45 should be used to perform the Channel Checks whenever possible.

The LOG function of an available calculator or the scientific calculator on the Control Room PC may be used to determine the logarithmic values. (NCR 268640) 8.2.5 IF MODE 3, 4 OR 5 shiNy checks are required, THEN PERFORM CHANNEL CHECK on the Source Range Neutron Flux monitors. (ITS SR 3.3.1.1, Table 3.3.1-1 Item 4)

INIT 07-19

1. Day Shift (07-19)

a. RECORD Nl-31 indication.

b. RECORD N-32 indication.

c. CALCULATE deviation: LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results: SAT / UNSAT (Circle one)

OST-020 Rev. 41 Page 25 of 54

Section 8.2 Page 16 of 17 8.2.5 (continued)

INIT 19-07

2. Night Shift (19-07)

a. RECORD Nl-31 indication.

b. RECORD Nl-32 indication.

c. CALCULATE deviation: LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results. SAT I UNSAT OST-020 Rev. 41 Page 26 of 54

Section 8.2 Page 17 of 17 8.2 (Continued) IMT INIT 07-19 19-07 8.2.6 IF movement of irradiated fuel assemblies in Spent Fuel Building OR Containment is occurring OR will occur, THEN PERFORM CHANNEL CHECK on the Control Room Radiation Monitor- R-1. (ITS SR 3.3.7.1, Table 3.3.7-1 Item 2) 8.2.7 IF the DSC is loaded OR being loaded AND is NOT sealed lAW ISFS-014, THEN PERFORM CHANNEL CHECK on the Control Room Radiation Monitor R-1 until notified by maintenance that the sealing operation is complete.

(ITS SR 3.3.7.1, Table 3.3.7-1 Item 2)

NOTE: ITS 3.3.6.1 and Table 3.3.6-1, Containment Ventilation Isolation Instrumentation, is applicable in modes 1, 2, 3, 4 OR during movement of RECENTLY irradiated fuel (decay time of less than 56 hours6.481481e-4 days 0.0156 hours 9.259259e-5 weeks 2.1308e-5 months ). Fuel is no longer recently irradiated if greater than 56 hours6.481481e-4 days 0.0156 hours 9.259259e-5 weeks 2.1308e-5 months have elapsed since reactor shutdown.

OP-920, Radiation Monitoring System, provides instructions for performing radiation monitor channel checks.

8.2.8 IF MODE 1, 2, 3, OR 4 shift checks are required, OR movement of RECENTLY irradiated fuel assemblies in Containment is occurring OR will occur, THEN PERFORM a CHANNEL CHECK on the Containment Radiation monitors.

(ITS SR 3.3.6.1, Table 3.3.6-1 Item 3.a and 3.b)

- R-11, CV AIR & PLANT VENT PARTICULATE

- R-12, CV AIR & PLANT VENT RADIOACTIVE GAS OST-020 Rev. 41 Page 27 of 54

Section 8.3 Page 1 of 13 INIT INIT 07-19 19-07 8.3 Reactor Coolant System 8.3.1 IF MODE 1 shiftly checks are required, THEN PERFORM the following:

1. VERIFY PZR Pressure is greater than or equal to 2205 psig. (ITS SR 3.4.1.1)

(07-19) psig (19-07) psig

2. VERIFY RCS Average Temperature is less than or equal to 579.4°F. (ITS SR 3.4.1.2)

(07-19)

(19-07) °F OST-020 Rev. 41 Page 28 of 54

Section 8.3 Page 2 of 13 8.3.1 (Continued) INIT INIT 07-19 19-07 NOTE: ITS SR 3.4.1.3 requires that the RCS Total Flow be verified to be greater than or equal to 97.3x1 06 Ibm/hr every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . RCS flow is not indicated in Ibm/hr.

Therefore, EST-047 was performed and provided the following values for performing this SR.

LOOP A LOOP B LOOP C Transmitter Mm Flow Transmitter Mm Flow Transmitter Mm Flow FT-414 98.81 FT-424 97.72 FT-434 101.94 FT-415 98.81 FT-425 97.04 FT-435 101.86 FT-416 98.76 FT-426 95.61 FT-436 102.26

3. IF ERFIS is available, THEN VERIFY RCS flow indicated on ERFIS is greater than the Mm Flow values provided. (ITS SR 3.4.1.3)

LOOP A LOOP B LOOP C Transmitter Flow Transmitter Flow Transmitter Flow

07 19 07 19 07 19 RCFO400A RCFO42OA RC F0440A (FT-414) (FT-424) (FT-434)

RCFO4O1A RCFO421 A RCFO441A (FT-41 5) (FT-425) (FT-435)

RCFO4O2A RCFO422A RCFO442A (FT-416) (FT-426) (FT-436)

OST-020 Rev. 41 Page 29 of 54

Section 8.3 Page 3 of 13 8.3.1 (Continued) INIT INIT 07-19 19-07 NOTE: ITS SR 3.4.1.3 requires that the RCS Total Flow be verified to be greater 6 Ibm/hr every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . RCS flow is not indicated in Ibm/hr.

than or equal to 97.3x10 Therefore, EST-047 was performed and provided the following values for performing this SR.

LOOP A LOOP B LOOP C Transmitter Mm Flow Transmitter Mm Flow Transmitter Mm Flow FT-414 98.81 FT-424 97.72 FT-434 101.94 FT-415 98.81 FT-425 97.04 FT-435 101.86 FT-416 98.76 FT-426 95.61 FT-436 102.26 NOTE: The marked increments of the RCS flow indicators on the RTGB are 2%.

This means they can not be read in less than 1% increments.

4. IF ERFIS is unavailable, THEN VERIFY RCS flow as follows: (ITS SR 3.4.1.3)

a. RECORD RCS flow as indicated on the RTGB.

LOOP A LOOP B LOOP c Transmitter Flow Transmitter Flow Transmitter Flow 07 19 07 19 07 19 FT-414 FT-424 FT-434 (RCFO400A) (RCFO42OA) (RCFO44OA)

FT-415 FT-425 FT-435 (RCFO4O1 A) (RCFO421 A) (RCFO441A)

FT-416 FT-426 FT-436 (RCFO4O2A) (RCFO422A) (RCFO442A)

OST-020 Rev. 41 Page 30 of 54

Section 8.3 Page 4 of 13 INIT INIT 8.3.1.4 (Continued) .,

07-19 19-07

b. IF any RTGB RCS flow indication for Loop I and Loop 2 is less than 100%, OR IF any RTGB RCS flow indication for Loop 3 is less than 101%, THEN contact RES for assistance in verifying RCS flow.

RESS Contact (Print name) 8.3.2 IF MODE I OR 2 shifty checks are required, THEN VERIFY each RCS Loop is in operation. (ITS SR 3.4.4.1) 8.3.3 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM the following:

NOTE: PZR Level limits are 63.3% when in MODE I and 92% when in MODE 2 OR 3.

1. VERIFY PZR Level is within limits.

(ITS SR 3.4.9.1) (07-19)

(19-07) %

NOTE: OP-920, Radiation Monitoring System, provides instructions for performing radiation monitor channel checks.

8.3.4 IF MODE 1, 2, 3 OR 4 shiftly checks are required, THEN PERFORM the following:

1. CHANNEL CHECK of the required CV Atmosphere Radioactivity Monitor. (ITS SR 3.4.15.1)

(07-19) Required Monitor R-11 I R-12 (Circle one)

(07-19) CHANNEL CHECK Complete (1 9-07) Required Monitor R-1 1 I R-1 2 (Circle one)

(19-07) CHANNEL CHECK Complete OST-020 Rev. 41 Page 31 of 54

Section 8.3 Page 5 of 13 8.3.4 (Continued) INIT 07-19

2. VERIFY Seal Injection flow of greater than or equal to 6 gpm to each RCP. (ITS SR 3.4.17.1) 07-19 FI-130, RCP A gpm FI-127, RCP B gpm FI-i24, RCP C gpm NOTE: IF FI-127, Fl-124 OR Fl-i 30 is OOS THEN manual calculation of Seal Injection Flow can be performed lAW OP-30i-1 to satisfy ITS SR 3.4.17.1. (ESR 99-00220)

IF Fl-i 30 is OOS, THEN notify maintenance to PERFORM PM 57033. (ITS LCO 3.4.17)

IF Fl-i 27 is OOS, THEN notify Maintenance to PERFORM PM 57032. (ITS LCO 3.4.17)

IF Fl-i 24 is OOS, THEN notify Maintenance to PERFORM PM 57031. (ITS LCO 3.4.17)

OST-020 Rev. 41 Page 32 of 54

Section 8.3 Page 6 of 13 8.3.4.2 (Continued) INIT 19-07 19-07 FI-130, RCP A 1 gpm FI-127, RCP B gpm Fl-124, RCP C gpm NOTE: IF Fl-127, Fl-I 24 OR Fl-I 30 is OOS THEN manual calculation of Seal Injection Flow can be performed lAW OP-301-1 to satisfy ITS SR 3.4.17.1.

(ESR 99-00220)

IF Fl-I 30 is OOS, THEN notify maintenance to PERFORM PM 57033. (ITS LCO 3.4.17)

IF Fl-I 27 is OOS, THEN notify Maintenance to PERFORM PM 57032. (ITS LCO 3.4.17)

IF FI-124 is OOS, THEN notify Maintenance to PERFORM PM 57031. (ITS LCO 3.4.17)

OST-020 Rev. 41 Page 33 of 54

Section 8.3 Page 7 of 13 INIT INIT 07-19 19-07 8.3.5 IF MODE 3 shiftly checks are required, THEN PERFORM the following:

VERIFY required RCS Loops are in operation.

(ITS SR 3.4.5.1)

2. VERIFY S/G secondary side water levels are greater than or equal to 16% NR for required RCS Loops.

(ITS SR 3.4.5.2) 07-19 S/G A %

SIG B T %

SIG C %

19-07 S/G A %

S/G B %

SIG C %

3. IF only one RCS loop is in operation, THEN PERFORM ONE of the following:

a. VERIFY the Rod Control System is not capable of rod withdrawal. (ITS SR 3.4.5.3)

b. VERIFY the Reactor Trip Breakers are open.

(ITS SR 3.4.5.4)

c. VERIFY the Lift Coil Disconnect Switches for all Control Rods not fully withdrawn are open.

(ITS SR 3.4.5.5)

OST-020 Rev. 41 Page 34 of 54

Section 8.3 Page 8 of 13 INIT INIT 07-19 19-07 8.3.6 IF MODE 4 shiftly checks are required, THEN PERFORM the following:

VERIFY one RHR train OR RCS Loop is in operation.

(ITS SR 3.4.6.1) (07-19) RHR I RCS (Circle one)

(19-07) RHR / RCS (Circle one)

2. VERIFY S/G secondary side water levels are greater than or equal to 16% NR for required RCS loops.

(ITS SR 3.4.6.2)

(0719) A! B I C %

(Circle one)

(1 907) A! B / C %

(Circle one)

OST-020 Rev. 41 Page 35 of 54

Section 8.3 Page 9 of 13 INIT INIT 07-19 19-07 NOTE: Steps 8.3.7 OR 8.3.8, along with step 8.3.9, are required to meet Low Temperature Overpressure Protection (LTOP) requirements of ITS LCO 3.4.12 in MODES 4 and 5.

When in MODES 4 OR 5, an OPERABLE Power Operated Relief Valve (PORV) will have a nominal lift setting of 400 psig and an allowed value of 418 psig.

8.3.7 IF MODE 4 OR 5 shiftly checks are required, and use of OPERABLE Power Operated Relief Valves is desired to meet Low Temperature Overpressure Protection per ITS LCO 3.4.12.a, THEN VERIFY the following:

1. Two Power Operated Relief Valves (PORVs) are operable and each associated PORV block valve is OPEN.

PCV-456, PZR PORV (07-19) OPERABLE RC-535, PORV BLOCK (07-19) OPEN PCV-455C, PZR PORV (07-19) OPERABLE RC-536, PORV BLOCK (07-19) OPEN PCV-456, PZR PORV (19-07) OPERABLE RC-535, PORV BLOCK (19-07) OPEN PCV-455C, PZR PORV (19-07) OPERABLE RC-536, PORV BLOCK (19-07) OPEN

2. A maximum of one Safety Injection (SI) pump capable of injecting into the RCS when all cold leg temperatures are 175°F.

3. No SI pump capable of injecting into the RCS when any cold leg temperature is <1 75°F.

OST-020 Rev. 41 Page 36 of 54

Section 8.3 Page 10 of 13 NOTE: ITS Bases for LCO 3.4.12 states for an RCS Vent to meet the flow capacity requirement, it requires removing a pressurizer safety valve, removing a PORVs internals or physically blocking the valve stem of the PORV in the open position, and disabling its block valve in the open position. ITS LCO 3.4.12.b identifies that the required vent size for the RCS to be considered vented is greater than or equal to 4.4 square inches. One safety valve removed provides an opening greater than 10 square inches. Both PORVs Blocked Open with the Block Valves Open are required to meet the 4.4 square inches.

The required frequency for ITS SR 3.4.12.5 is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . This SR is performed shiftly for ease of tracking, since there is no OST which is performed on a 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months frequency.

INIT INIT 07-19 19-07 8.3.8 IF MODE 4 OR 5 shiftly checks are required, and use of a depressurized RCS with a vent path of 4.4 square inches, is desired to meet Low Temperature Overpressure Protection per ITS LCO 3.4.12.b, THEN VERIFY the following:

1. IF using Safety Valve Removed to comply with ITS LCO 3.4.12.b, THEN VERIFY at least ONE Safety Valve removed and FME cover not restricting flow.

a. RC-551A I RC-551 B I RC-551 C Circle One Removed (07-19)

b. RC-551A I RC-551B I RC-551C Circle One Removed (19-07)

OST-020 Rev. 41 Page 37 of 54

Section 8.3 Page 11 of 13 8.3.8 (continued) INIT INIT 07-19 19-07

2. IF using PORVs to comply with ITS LCD 3.4.12.b, THEN VERIFY both PZR PORVs are BLOCKED OPEN lAW OP-006 AND the associated Block Valves are OPEN.

PCV-456, PZR PORV (07-19) BLOCKED OPEN RC-535, PORV BLOCK (07-19) OPEN

- PCV-455C, PZR PORV (07-19) BLOCKED OPEN

- RC-536, PORV BLOCK (07-19) OPEN PCV-456, PZR PORV (19-07) BLOCKED OPEN

- RC-535, PORV BLOCK (19-07) OPEN

- PCV-455C, PZR PORV (19-07) BLOCKED OPEN

- RC-536, PORV BLOCK (19-07) OPEN OST-020 Rev. 41 Page 38 of 54

Section 8.3 Page 12 of 13 INIT INIT 07-19 19-07 NOTE: ITS LCO 3.4.12 contains a Note which amplifies when SI Accumulators are required to be isolated. The following step is a simplified method to ensure compliance and eliminates the need to use ITS LCO 3.4.3 curves.

8.3.9 IF MODE 4 OR 5 shiftly checks are required and any SI Accumulator is pressurized, THEN VERIFY each SI Accumulator isolation valve is closed AND deenergized for Low Temperature Overpressure Protection.

(ITS SR 3.4.12.3)

1. SI Accumulator A SI-865A, ACCUMULATOR A DISCHARGE (07-19) CLOSED (19-07) CLOSED

- SI-865A, ACCUMULATOR A DISCHARGE breaker on MCC-5, CMPT 14F (07-19) OPEN (19-07) OPEN

2. SI Accumulator B

- Sl-865B, ACCUMULATOR B DISCHARGE (07-19) CLOSED (19-07) CLOSED Sl-865B, ACCUMULATOR B DISCHARGE breaker on MCC-6, CMPT 1OJ (07-19) OPEN (19-07) OPEN OST-020 Rev. 41 Page 39 of 54

Section 8.3 Page 13 of 13 8.3.9 (Continued) INIT INIT 07-19 19-07

3. SI Accumulator C

- SI-865C, ACCUMULATOR C DISCHARGE (07-19) CLOSED (19-07) CLOSED

- Sl-865C, ACCUMULATOR C DISCHARGE breaker on MCC-5, CMPT 9F (07-19) OPEN (19-07) OPEN 8.3.10 IF MODE 5 shiftly checks are required, THEN PERFORM the following:

VERIFY one RHR Train is in operation.

(ITS SR 3.4.7.1 and 3.4.8.1) (07-19) A / B (Circle one)

(1 907) A I B (Circle one)

2. IF RCS loops are filled AND only one RHR train is operable, THEN VERIFY S/G secondary side water level is greater than or equal to 16% NR in the required S/G. (ITS SR 3.4.7.2)

(0719) A I B I C (Circle one)

(1907) A I B I C (Circle one)

OST-020 Rev. 41 Page 40 of 54

Section 8.4 Page 1 of 4 INIT INIT 07-19 19-07 8.4 Emergency Core Cooling Systems 8.4.1 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM the following:

IF RCS pressure is greater than 1000 psig, THEN PERFORM the following:

a. VERIFY Borated Water Volume in each SI Accumulator is greater than or equal to 825 ft 3 (61.5%) and less than or equal to 841 ft 3 (80.4%). (ITS SR 3.5.1.2)

SI Accumulator A (07-19) %

SI Accumulator B (07-19) %

SI Accumulator C (07-19) %

SI Accumulator A (19-07) %

SI Accumulator B (19-07)

SI Accumulator C (19-07) %

OST-020 Rev. 41 Page 41 of 54

Section 8.4 Page 2 of 4 8.4.1.1 (Continued)

IN]I INII 07-19 19-07

b. VERIFY Nitrogen Cover pressure in each SI Accumulator is greater than or equal to 600 psig and less than or equal to 660 psig.

(ITS SR 3.5.1.3)

SI Accumulator A (07-19) psig SI Accumulator B (07-19) psig SI Accumulator C (07-19) psig SI Accumulator A (19-07) psig SI Accumulator B (19-07) psig SI Accumulator C (19-07) psig OST-020 Rev. 41 Page 42 of 54

Section 8.4 Page 3 of 4 8.4.1 (Continued)

IILI INI[

07-19 19-07

2. VERIFY the following valves are in the listed positions with Control Power to the valve operator removed.

(ITS SR 3.5.2.1)

SI-862A, RWST to RHR OPEN SI-862B, RWST to RHR OPEN

- Sl-863A, RHR LOOP RECIRC CLOSED

- Sl-863B, RHR LOOP RECIRC CLOSED SI-864A, RWST DISCH OPEN Sl-864B, RWST DISCH OPEN

- Sl-866A, LOOP 3 HOT LEG INJ CLOSED SI-866B, LOOP 2 HOT LEG INJ CLOSED

- SI-878A, SI DISCH CROSS CONN OPEN SI-878B, SI DISCH CROSS CONN OPEN SI-862A AC Control Power Defeat Switch Defeated Sl-862B AC Control Power Defeat Switch Defeated OST-020 Rev. 41 Page 43 of 54

Section 8.4 Page 4 of 4 8.4.1.2 (Continued) INIT IMT 07-19 19-07 SI-863A AC Control Power Defeat Switch Defeated SI-863B AC Control Power Defeat Switch Defeated Sl-864A AC Control Power Defeat Switch Defeated SI-864B AC Control Power Defeat Switch Defeated Sl-866A AC Control Power Defeat Switch Defeated SI-866B AC Control Power Defeat Switch Defeated SI-878A breaker on MCC-5 in CMPT No. 20 OPEN Sl-878B breaker on MCC-6 in CMPT NO. 15C OPEN OST-020 Rev. 41 Page 44 of 54

Section 8.5 Page 1 of I INIT INIT 07-19 19-07 8.5 Containment Systems 8.5.1 IF MODE 1, 2, 3 OR 4 shiftly checks are required, THEN PERFORM the following:

1. VERIFY CV Pressure is greater than or equal to

-0.8 psig and less than or equal to 1.0 psig.

(ITS SR 3.6.4.1)

(07-19) psig (19-07) psig

2. VERIFY IVSW Tank Pressure is greater than or equal to 49 psig (includes instrument uncertainties)

(NCR 188409) indicated locally on P1-1910 OR as indicated on a locally installed temporary gage with an accuracy equal to or less than +/-2 psig.

(ITS SR 3.6.8.1)

(07-19) psig (19-07) psig OST-020 Rev. 41 Page 45 of 54

Section 8.6 Page 1 of 1 INIT INIT 07-19 19-07 8.6 Plant Systems 8.6.1 IF MODE 1, 2, 3 shiftly checks are required OR mode 4 shiftly checks are required when any SIG is being used for heat removal, THEN PERFORM the following:

NOTE: 8S1 9-P-I 01 allows 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of operation with CST level between 50%

and 26%.

If LI-1454A or Ll-1454B is unavailable, LI-1454C may be used to check CST level.

CST level indications used should be within 5% of one another to satisfy OST-023 and OST-918 requirements. (ITS 3.3.3 Table 3.3.3-1 item 14.)

I. VERIFY CST Level is greater than or equal to 50%. (Admin.

limit per 8S19-P-101 & Appendix R Separation Analysis)

(ITS SR 3.7.5.1 limit of 35,000 gallons (26%)).

LI-1454A (07-19)

LI-1454B (07-19)

LI-1454A (19-07)

LI-1454B (19-07) 8.6.2 IF MODE 1, 2, 3, 4, OR 5 shiftly checks are required, OR during movement of irradiated fuel assemblies, THEN PERFORM the following:

1. VERIFY Control Room temperature is less than or equal to 85°F using TIC-6513 if available OR a calibrated thermometer placed near the return duct inlet. (TRMS TR 4.7.1)

(07-19) TIC-6513 (19-07) TIC-6513 Calibrated Thermometer (07-19)

Calibrated Thermometer (19-07)

OST-020 Rev. 41 Page 46 of 54

Section 8.7 Page 1 of4 INIT INIT 07-19 19-07 8.7 Other 8.7.1 IF MODE 1, 2, 3,4 OR 5 shiftly checks are required, THEN VERIFY the following Dedicated Shutdown/SBO Equipment:

1. DS Diesel Fuel Oil Storage Tank level greater than or equal to 2500 gallons. (07-19) gal (19-07) gal OST-020 Rev. 41 Page 47 of 54

Section 8.7 Page 2 of 4 INIT INIT 07-19 19-07 NOTE: This section should be performed during dayshift when Unit 1 Chemistry personnel will be available.

8.7.2 IF Mode 1, 2, 3, OR 4 daily checks are required, THEN PERFORM the following:

1. RECORD the ERFIS reading for CWT9O21A, Black Creek Temperature. °F NL NOTE: Reviewing the Circulating Water Effluent Monitoring Log hourly print out will aid in performance of this step.

2. RECORD ERFIS reading for CWT2400A, TE-3091A, COND A CW Inlet Temp

°F N/A

3. COMPARE ERFIS point CWT9O21A, Black Creek Temperature, to the temperature in 8.7.2.2 AND RECORD the difference.

[CAPR,NCR00290724] °F N/A NOTE: Temperature indication will not be reliable if there is no circulating water flow (i.e. water box not in service). Additionally a margin of 3°F OR greater could be caused by wind direction, lake level, and stratification due to rainfall, or other possible causes. No additional checks required when differences can be explained and no instrument failures suspected.

4. IF CWT9O2IA varies from ERFIS point CWT2400A by 3°F OR greater AND cannot be explained, THEN PERFORM the following:

a. REQUEST Unit 1 Control Room to have Unit 1 Chemistry personnel CHECK local temperature using a calibrated temperature instrument for comparison. N/A OST-020 Rev. 41 Page 48 of 54

Section 8.7 Page 3 of 4 8.7.2.4 (Continued)

INIT INIT 07-19 19-07 NOTE: The following step requires that a WR be initiated for the suspect instrument when the margin is 2°F or greater between ERFIS point CWT9021A and the calibrated temperature instrument. However, latitude should be given to reflect that the two instruments may not take temperatures in the same location in the flow stream and as such are affected by stratification caused by a rise in tail flow and associated rainfall. A work request is not needed when the difference can be explained and no instrument failure is suspect.

b. IF a delta of 2°F OR more is observed between ERRS point CWT9O21A AND the calibrated temperature instrument, THEN INITIATE a work request for the suspect temperature instrument AND perform all applicable actions of PLP-023. W/R# N/A

5. RECORD the ERFIS reading for CWT9O22A, Discharge Canal Weir temperature. °F NL NOTE: Step 8.7.2.6 may be performed by contacting the Unit I Control Room.

6. From Unit I Contro Board Indication for Discharge Canal Weir temperature, RECORD the temperature.

°F N/A OST-020 Rev. 41 Page 49 of 54

Section 8.7 Page 4 of 4 INIT INIT 07-19 19-07 8.7.2 (Continued)

7. PERFORM a channel check on ERFIS point CVVT9O22A, Discharge Canal Weir temperature, by comparing to the reading from the Unit I Control Board Indication for Discharge Canal Weir temperature AND RECORD the difference.

[CAPR NCR 290724] °F____

8. IF CWT9O22A varies from the Unit I Control Board Indication by 3 degrees OR greater AND the delta cannot be explained, THEN PERFORM the following:

a. REQUEST Unit I Control Room to have Unit 1 Chemistry personnel CHECK local temperature using a calibrated temperature instrument for comparison. N/A NOTE: The following step requires that a WR be initiated for the suspect instrument when the margin is 2°F or greater between ERFIS point CWT9O22A and the calibrated temperature instrument. However, latitude should be given to reflect that the two instruments may not take temperatures in the same location in the flow stream and as such are affected by stratification caused by a rise in tail flow and associated rainfall. A work request is not needed when the difference can be explained and no instrument failure is suspect.

b. IF a delta of 2 degrees OR more is observed between ERFIS point CWT9O22A AND the calibrated temperature instrument, THEN INITIATE a work request for the suspect temperature instrument.

W/R# N/A OST-020 Rev. 41 Page 50 of 54

Section 8.7 Page 4 of 4 INIT INIT NOTE: When the SI accumulators are pressurized AND Boron Injection to RCS Check Valve leakage is present this section should be performed to maintain the BIT header pressure above 650 psig. (Sl-873C/SI-873F, SI-873B/SI-873E, OR SI-873ASl-873D)

APP-002-C3, BIT HDR HI PRESS, provides guidance for draining the BIT line via an SI pump(s) to relieve the BIT Header pressure.

OP-202-1, SI System Venting, provides guidance to re-pressurize the BIT header if it becomes necessary.

PT-943 and PT-940 can be used to trend pressure changes which would indicate potential leakage into and out of the piping sections.

8.7.3 IF Accumulator to SI check valves leakage is present, THEN PERFORM the following:

1. CHECK AND RECORD BIT Header Pressure (P1-934).

(07-19) psig (19-07) psig

2. IF BIT Header Pressure (P1-934) is less than 650 psig, THEN PERFORM OP-202-1, Section 8.15.

(07-19)

(19-07)

OST-020 Rev. 41 Page 51 of 54

9.0 RECORDS 9.1 The completed procedure and any partials are forwarded to Plant Records.

10.0 ATTACHMENTS 10.1 Surveillance Test Procedure Certification and Review Form (Shift 07-19) 10.2 Surveillance Test Procedure Certification and Review Form (Shift 19-07)

OST-020 Rev. 41 Page 52 of 54

ATTACHMENT 10.1 Page 1 of I SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM SHIFT 07-19 Scheduled / Unscheduled (Circle one)

(If unscheduled, state reason for test and the page numbers included in partial test)

Initials Name (Print) Date Test Performed By:

Test Complete: Date: Time:_____________

Test Satisfactory: Yes / No (Circle one)

Reviewed by:

Shift Technical Advisor Date Comments: (Required if results were unsatisfactory)

Approved by:

Shift Manager Date OST-020 Rev. 41 Page 53 of 54

ATTACHMENT 10.2 Page 1 of 1 SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM SHIFT 19-07 Scheduled I Unscheduled (Circle one)

(If unscheduled, state reason for test and the page numbers included in partial test)

Initials Name (Print) Date Test Performed By:

Test Complete: Date:____________ Time:

Test Satisfactory: Yes / No (Circle one)

Reviewed by:

Shift Technical Advisor Date Comments: (Required if results were unsatisfactory)

Approved by:

Shift Manager Date OST-020 Rev. 41 Page 54 of 54

0 0 CD)

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Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.:

Task

Title:

Calculate the Maximum Permissible JPM No.: 2011-2 NRC JPM Admin Stay Time with Emergency Dose Limits RO A3 K/A

Reference:

G2.3.4 (3.2/3.7)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

An emergency event has been declared.

A Containment entry would enhance the pressure control of the plant but is NOT required to protect valuable plant equipment.

The tasks to be performed are:

Task Task Time Dose Number Req ui red Rate (R/hr)

(minutes)

Fail closed PCV-455A 8 21.42 Manually open RC-536 6 3.65 Manually close CVC- 9.51 312 NOTE: Assume that NO dose is received while traveling between the tasks.

Task Standard: Calculate the dose received and the maximum time allowed to perform the final task.

Required Materials: Calculator NGGM-PM-0002 General

References:

NGGM-PM-0002, EPCLA-01 2011-2 NRC JPM Admin RO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Handouts: NONE Initiating Cue: The Inside Auxiliary Operator has completed Tasks #i and 2 in the time required.

How long does he have to complete Task #3 without exceeding the applicable Emergency Dose Limit?

(Perform all calculations to 2 decimal places)

Time Critical Task: NO Validation Time: 10 minutes SIMULATOR SETUP N/A 2011-2 NRC JPM Admin RO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 7 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

START TIME:

Performance Step: I Determine the dose received while performing Task #1.

Standard: Candidate determines the dose received while performing Task

1:

21.42 R/hr X 8 minutes X 1 hour/60 minutes = 2.86 R.

Examiners Note:

Comment:

Performance Step: 2 Determine the dose received while performing Task #2.

Standard: Candidate determines the dose received while performing Task

2:

3.65 R/hr X 6 minutes X 1 hour/60 minutes =0.37 R.

Examiners Note:

Comment:

2011-2 NRC JPM Admin RO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 7 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 3 Determine the remaining dose to reach the Emergency Dose Limit.

Standard: Candidate calculates the dose remaining for the Emergency Dose Limit:

5.00 R2.86 RO.37 R= 1.77 R Examiners Note:

Comment:

Performance Step: 4 Determine the time available for the Inside Auxiliary Operator to complete Task #3 with exceeding the Emergency Dose Limit.

Standard: Candidate determines within +1, 3 minutes the time available for the Inside Auxiliary Operator to complete Task #3 without exceeding the Emergency Dose Limit:

Available Dose! Dose Rate = 1.77 RI 9.51 R!hr 0.19 hrs 0.19 hrs X 60 minutes/i hour = 11.4 minutes (ii minutes 24 seconds)

Allowable tolerance of 11 .22 minutes (11 minutes, 13 seconds) to 11.4 minutes (11 minutes, 24 seconds)

Examiners Note:

Comment:

2011-2 NRC JPM Admin ROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 7 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Termination Cue: When the candidate has calculated the allowable dose for Task #3, the evaluation of this JPM is complete.

STOP TIME:

2011-2 NRC JPM Admin ROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 7 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM Admin RO A3 Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPMAdmin ROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 7 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

An emergency event has been declared.

A Containment entry would enhance the pressure control of the plant but is NOT required to protect valuable plant equipment.

The tasks to be performed are:

Task Task Time Dose Number Required Rate (R/hr)

(minutes) 1 Fail closed PCV-455A 8 21.42 2 Manually open RC-536 6 3.65 3 Manually close CVC- 9.51 312 NOTE: Assume that NO dose is received while traveling between the tasks.

INITIATING CUE: The Inside Auxiliary Operator has completed Tasks #1 and 2 in the time required.

How long does he have to complete Task #3 without exceeding the applicable Emergency Dose Limit?

(Perform all calculations to 2 decimal places) 2011-2 NRC JPM Admin RO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 7 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

An emergency event has been declared.

A Containment entry would enhance the pressure control of the plant but is NOT required to protect valuable plant equipment.

The tasks to be performed are:

Task Task Time Dose Number Required Rate (RIhr)

(minutes) 1 Fail closed PCV-455A 8 21.42 2 Manually open RC-536 6 3.65 3 Manually close CVC- 9.51 312 NOTE: Assume that NO dose is received while traveling between the tasks.

INITIATING CUE: The Inside Auxiliary Operator has completed Tasks #1 and 2 in the time required.

How long does he have to complete Task #3 without exceeding the applicable Emergency Dose Limit?

(Perform all calculations to 2 decimal places) 2011-2 NRC JPM Admin RO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 02341101103 Task

Title:

Heat Stress Work Limits JPM No.: 2011-2 NRC JPM SRO Al-i K)A

Reference:

G2.1.26 3.4/3.6 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

Plant is in Mode 3 with RCS cooldown in progress.

RHR System needs to be aligned for core cooling lAW GP-007 and OP-201

2 AOs have been briefed on performing the valve alignments.

Work time is 30 minutes per AC (1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months total)

RC has determined that OREX coveralls will be used.

Task Standard: Candidate is to determine the following:

Metabolic heat load

Action time in minutes

Recovery period in minutes Required Materials: AP-020, Heat Stress Program, Revision 16 General

References:

AP-020, Heat Stress Program Handouts: AP-020, Heat Stress Program Initiating Cue: Using AP-020, Complete Attachment 10.3 to determine the metabolic heat load, allowable working time and recovery period for work in the specified plant area. This is a succeeding evaluation. Additional information on CUE sheet.

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C1 Worksheet Time Critical Task: NO Validation Time: 12 minutes 2011-2 NRC Admin JPM SRO Al-I NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 8 Form ES-C-I PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk *

)

Start Time:

Performance Step: I Candidate reviews AP-020 Attachment 10.3, Heat Stress Evaluation Form Standard: Candidate reviews AP-020 Attachment 10.3, Heat Stress Evaluation Form Examiners Note:

Comment:

Performance Step: 2 Determine the correct clothing for the type of job. (Step 8.1.4)

Standard: Candidate determines that Attachment 10.2, Page 4 of 11, OREX over Scrub Suit (CS) or SMS polypropylene coveralls (PP) over Scrub Suit (CS) is the proper attachment to be used in the heat stress determination.

Examiners Note:

Comment:

2011-2 NRC Admin JPM SRO Al-I NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 8 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 3 Determines the Metabolic Heat Load to be Moderate Work.

(Step uses Attachment 10.1)

Standard: Candidate determines performing valve alignments to be Moderate Work Examiners Note:

Comment:

Performance Step: 4 Determines the temperature in the Auxiliary Building Pipe Alley Standard: Candidate circles Estimate for WBGT on Attachment 10.3 Examiners Note: Candidate uses Attachment 10.4, Estimating WBGT to estimate WBGT from dry temperature.

Comment:

Performance Step: 5 Determines WBGT to be 101°F Standard: Candidate determines WBGT to be Dry bulb plus 4°F from Attachment 10.4 (97°F +4°F =101°F)

Examiners Note:

Comment:

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 8 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 6 Determines Action Time to be 35 minutes Standard: Candidate uses Attachment 10.2 to determine Action Time to be 35 minutes. Page 4 of 11, Recommended Heat Stress Control Action Times OREX Over Scrub Suit (CS) for Moderate Work at 101°F WBGT Examiners Note:

Comment:

Performance Step: 7 Determines the Recovery time to be 51 minutes (Step 8.3.1)

Standard: Candidate uses 30 minutes as time in hot environment (2 men working for 1.0 person hour)

(30*60)/35 = (1800/35) = 51.4 Minutes (Range of 51 to 52 minutes)

Examiners Note:

Comment:

Performance Step: 8 Circles YES for the workers have received a pre-job brief including Heat Stress Concerns Standard: Candidate circles YES, this information was in the initial conditions.

Examiners Note:

Comment:

Performance Step: 9 Sign and Date Attachment 10.3 Standard: Candidate reviews and then signs and dates Attachment 10.3 Examiners Note:

Comment:

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 8 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Terminating Cue: Candidate completes Heat Stress Evaluation Form STOP TIME:

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 8 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.:* 2011-2 NRC Admin JPM SRO Al-i Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

______F ATTACHMENT 10.3 Page 1 of 1 JOBDATE: fa 1 rz / / A HEAT STRESS EVALUATION FORM A

y*

JOB LOCATION. A1(3(

TASK(S):/9/

LI SUPERVISOR:

EST. PERSON-HOURS:

4o NUMBER OF WORKERS: 2 PLANT STATUS (for job planning use):

Mtit \

CLOTHING TYPE:

ex (

W 1 4t//

METABOLIC HEAT LOAD (CIRCLE ON LIGHT MODERATE HEAVY TEMPERATURE (CIRCLE ONE):

MEASUREMENT WBGT=

DB= WB= GT=

ACTION TIME minuses (from Attachment 10.2)

RECOVERY PERIOD =j/fminutes = (Time in minutes in Hot Environment) x (60)

(Action Time in minutes)

HAVE WORKERS RECEIVED A PRE-JOB BRIEFING INCLUDING HEAT STRESS CONCERNS?

(C CLE ONE)

YES NO DITIONAL INFORMATION:

Signature (Job Supervisor):

AP-020 Rev. 16 Page 27 of 33

Appendix C Page 8 of 8 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

Plant is in Mode 3 with RCS cooldown in progress.

RHR System needs to be aligned for core cooling lAW GP-007 and OP-201

2 AOs have been briefed on performing the valve alignments.

Work time is 30 minutes per AO (1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months total)

RC has determined that OREX overalls will be used.

INITIATING CUE: Using AP-020, Complete Attachment 10.3 to determine the metabolic heat load, allowable working time and recovery period for work in the specified plant area. This is a succeeding evaluation.

Work to be performed Valve alignments in overhead Pipe Alley Thermometer: 97°F Relative Humidity: Not Available Pipe Alley is a Contaminated Area 2Oii-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 8 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

Plant is in Mode 3 with RCS cooldown in progress.

RHR System needs to be aligned for core cooling lAW GP-007 and OP-201

2 ACs have been briefed on performing the valve alignments.

Work time is 30 minutes per AC (1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months total)

RC has determined that OREX overalls will be used.

INITIATING CUE: Using AP-020, Complete Attachment 10.3 to determine the metabolic heat load, allowable working time and recovery period for work in the specified plant area. This is a succeeding evaluation.

Work to be performed Valve alignments in overhead Pipe Alley Thermometer: 97°F Relative Humidity: Not Available Pipe Alley is a Contaminated Area 2011-2 NRC Admin JPM SRO Al-i NUREG 1021, Revision 9, Supplement 1

H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 PLANT OPERATING MANUAL VOLUME 1 PART 1 AP-020 HEA T STRESS PROGRAM REVISION 16 AP-020 Rev. 16 Page 1 of 33

SUMMARY

OF CHANGES PRR 00476573 AP-020 REVISION 16 H STEPISECTION Attachment 10.2 REVISION COMMENTS Updated NOTE to include (refer to 8.4.2) for PCR references - Editorial AP-020 Rev. 16 Page 2 of 33

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE .4

2.0 REFERENCES

4 3.0 RESPONSIBILITIES 4 4.0 PREREQUISITES 6 5.0 PRECAUTIONS AND LIMITATIONS 7 6.0 SPECIAL TOOLS AND EQUIPMENT 8 7.0 ACCEPTANCE CRITERIA 8 8.0 INSTRUCTIONS 9 8.1 Heat Stress Evaluation 9 8.2 Use of Recommended Action Times 10 8.3 Determination of Recovery Period Times 11 8.4 Use of Personal Cooling Devices 11 8.5 Use of Supplied Air Hoods 12 8.6 First Aid For Heat Illness 12 9.0 RECORDS 14 10.0 ATTACHMENTS 14 10.1 METABOLIC HEATLOADGUIDELINES 15 10.2 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES 16 10.3 HEAT STRESS EVALUATION FORM 27 10.4 ESTIMATING WBGT 28 10.5 USING THE WET BULB GLOBE THERMOMETER 29 10.6 HEAT STRESS PRE-JOB BRIEFING 30 10.7 DEFINITIONS 31 AP-020 Rev. 16 Page 3 of 33

1.0 PURPOSE 1 .1 The purpose of this procedure is to provide guidance to management and all employees for preventing heat-induced illnesses while performing work activities on the plant site.

2.0 REFERENCES

2.1 EPRI NP-4453-L, Heat Stress Management Program for Nuclear Power Plants Revision 1, Aug. 1991.

2.2 Clothing Update of EPRI NP-4453-L, 1991 Report, TR-1 09445, Final Report, July 1998.

2.3 CP&L Corporate Guidance Document SAF-CPL-032 Heat Stress.

2.4 NCR 49246, Use Of Tube Suits 3.0 RESPONSIBILITIES 3.1 Section Managers - Robinson Plant are responsible for:

3.1.1 Ensuring that personnel who perform work in moderate/high heat stress work environment(s) follow the guidelines in this procedure.

3.1.2 Ensuring that supervisors follow this the guidelines in this procedure when planning work in moderate/high heat stress work environments.

3.2 Supervisors are responsible for:

3.2.1 Ensuring that heat stress mitigation has been considered during job planning. The work crew supervisor or designee shall determine the Wet Bulb Globe Temperature and metabolic heat load using the guidance available in Attachments 10.1, 10.2 and 10.6.

3.2.2 Ensuring that either Attachment 10.3, Heat Stress Evaluation Form is completed, OR that proper means of determining action times and control measures have taken place and have been included as part of pre-job planning when Heat Stress has been determined to be an issue.

AP-020 Rev. 16 Page 4 of 33

3.2.3 Ensuring that a pre-job briefing is conducted prior to workers entering the high temperature environment to perform work. The Precautions and Limitations found in section 5.1 of this procedure should be covered in the briefing.

3.2.4 Ensuring that proper control methods are used to protect against heat stress.

3.2.5 Ensuring that all heat-stress caused incidents which require medical attention are recorded on FRM-SUBS-00979, Injury and Illness Incident Report Form. These forms can be obtained on the Progress Energy I ntranet.

3.3 Individuals are responsible for:

3.3.1 Following instructions for the handling of body cooling devices and using them as needed to prevent heat stress.

3.3.2 Being attentive to symptoms of heat stress while working in moderate/high heat stress work environments, stopping work, leaving it in a safe condition, and exiting the hot environment, if they feel ill due to heat stress.

3.3.3 Reporting to their supervisor any occurrence of heat stress or heat related illness.

3.3.4 Reporting to their supervisor any condition that might adversely impact their ability to perform their duties as a Fire Brigade Member. These conditions include but are not limited to general health, illness, medications, etc.

3.4 RC Unit is responsible for:

3.4.1 Providing Ice vests for work activities inside the RCA.

3.5 Unit 2 Control Room personnel are responsible for ensuring actions are taken to provide first aid or medical attention when notified of conditions involving heat stress victims.

AP-020 Rev. 16 Page 5 of 33

3.6 Site Industrial Hygiene and Safety Representative is responsible for:

3.6.1 Providing technical assistance on heat stress issues, including the development of plant heat stress training programs and maintenance of this procedure.

3.6.2 Ensuring that instruction on heat stress mitigation is arranged and conducted for employees prior to initial work in high temperature environments.

3.6.3 Assisting supervisors in the implementation of this procedure, when requested.

3.7 Maintenance is responsible for:

3.7.1 Maintaining and issuing Tube Suits.

40 PREREQUISITES N/A AP-020 Rev. 16 Page 6 of 33

5.0 PRECAUTIONS AND LIMITATIONS NOTE: These precautions should be covered in employee training as well as in the pre-job briefings prior to performing moderate or high heat stress work.

During time-critical evolutions involving emergency response where the safety of personnel and the public is a critical issue, personnel may not be able to comply with all of the requirements of this procedure. All reasonable attempts should be made to ensure the safety of personnel involved in the emergency response without compromising the timely completion of the response.

5.1 If an individual begins to feel symptoms of heat illness, the person should put their work in a safe condition, exit the area, notify their supervisor, rest in a cool area, and drink fluids. The Control Room should be called at ext. 5555 if symptoms persist in order to dispatch appropriate site first aid providers.

5.2 All jobs in high temperature environments should address heat stress controls in the planning stages. Planned action times and the use of body cooling devices should be considered.

5.3 Individuals who work in high temperature environments for the first time are more susceptible to heat illness than those accustomed to hot environments. After working in hot environments for several days, their bodies tend to acclimatize to heat exposure and they may tolerate longer heat exposures at higher work rates.

5.4 Work shall be planned so that an adequate number of workers are prepared to work in a high temperature environment. Workers should never work alone in high heat stress areas.

5.5 Individuals vary greatly in their tolerance to heat exposure. Factors which may affect heat tolerances may include:

Age

Weight

Sex

physical fitness

general health

colds, viruses, and infections

some medications

consumption of alcoholic beverages AP-020 Rev. 16 Page 7 of 33

5.6 In situations where individuals know that their work schedule for the following day involves entering a heat stress area, they should drink plenty of liquids in the 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to reporting to work.

5.7 Whenever feasible, engineering controls should be used to eliminate/reduce the heat exposure (i.e., isolation of the heat source, introduction of cooled air, circulation of present air, reduced humidity, etc.). The impact of these engineering controls should be reviewed with the Radiation Control (RC) unit for jobs in radiologically controlled areas.

5.8 Individuals who work in high temperature environments may become dehydrated due to sweating. Lost body water and electrolytes should be replaced at rest breaks to prevent heat-related illness. Liquids designed to replace these electrolytes (gatorade) may be obtained from the bulk warehouse prior to or after entry, and should be consumed in frequent, small amounts. (Salt tablets are not recommended.)

5.9 Individuals who work in high temperature environments must periodically rest in a cooler area to shed body heat. Duration of breaks, extent of clothing removal, and rest area should be determined by the job supervisor, using the guidance in Step 8.3.1. Certain employees may require longer rest periods than others.

5.10 Workers should be encouraged to drink one pint of water/fluid per hour of scheduled work prior to entering high heat stress areas.

5.11 Workers should also be encouraged to drink water/fluids after high temperature work to maintain fluid balance.

5.12 Where feasible, high heat stress work should be scheduled to minimize thermal stress in the work area. This includes scheduling work at times where the WBGT and/or the metabolic heat load are lower and/or protective clothing requirements are less restrictive.

5.13 For pre-job briefings in heat stress related work areas, utilize Attachment 10.6 during the briefing.

6.0 SPECIAL TOOLS AND EQUIPMENT N/A 7.0 ACCEPTANCE CRITERIA N/A AP-020 Rev. 16 Page 8 of 33

8.0 INSTRUCTIONS 8.1 Heat Stress Evaluation 8.1.1 The heat stress evaluation process involves assessing the variables that effect heat stress, including WBGT measurements, metabolic work load, clothing type and recovery periods. These factors are converted to recommended action times without regard to personal cooling devices for job planning purposes. A Heat Stress Evaluation Form, Attachment 10.3, may be used for heat stress job planning.

NOTE: The Temperature/Relative Humidity meters should be placed in the shade, where possible. These meters may display inaccurate readings if in direct sunlight (higher than actual temperature and lower than actual relative humidity). The crew supervisor/designee should contact the Site Industrial Hygiene and Safety Representative for assistance in conducting Heat Stress Evaluations.

8.1.2 The work crew supervisor/designee should measure the WBGT of the work area when he/she feels that heat stress conditions may exist.

WBGT is calculated using the following WBGT formulas:

Indoor WBGT = (0.7 x wet bulb) + (0.3 x globe)

Outdoor WBGT = (0.7 x wet bulb) + (0.2 x globe) + (0.1 x dry bulb)

Initial WBGT readings should be made with a Wet Bulb Globe Thermometer, available from the calibration lab. Instructions for the use of the Wet Bulb Globe Thermometer are found on Attachment 10.5, Using the Wet Bulb Globe Thermometer. Measurements should be representative of the work area thermal load. Succeeding evaluations may be based solely on dry bulb temperature and relative humidity by using Attachment 10.4, Estimating WBGT. Temperature/Relative Humidity meters are posted at various locations around site to assist with conducting these estimates. Charts on these meters have been developed in accordance with Attachment 10.4, and should be consulted to assist in the estimation of WBGT.

AP-020 Rev. 16 Page 9 of 33

8.1.3 The work crew supervisor/designee should determine the metabolic heat load using the guide available in Attachment 10.1.

8.1.4 The work crew supervisor/designee should determine the type of work clothing required or being used for the job. The categories include; work clothes (WC), cloth coveralls (CC), cloth covera(ls over scrub suit (CS),

double cloth coveralls (DC), OREX coveralls, SMS polypropylene coveralls (PP), MB polyethylene coveralls (PE), polyester coveralls (P2),

polyester coveralls with scrubs (PS), water-barrier vapor-permeable coveralls (WB-1), water barrier vapor-permeable coveralls (WB-2),

vapor-barrier coveralls (VB), encapsulating suit or turn-out gear (ES),

flame retardant shirt and pants (FR).

8.2 Use of Recommended Action Times 8.2.1 Knowing the WBGT measurements, metabolic heat load, and protective clothing used, the work crew supervisor or designee should determine the planned action time from Attachment 10.2 and identify the desired methods to mitigate heat stress if longer work times are necessary.

8.2.2 Action times are used for job planning. Action times are absolute because of the great variability in worker response to heat-stress. Some workers could experience heat stress symptoms prior to reaching the maximum action time.

8.2.3 By using the planned action time limits and assessing the physical condition of the workers, the work crew supervisor or designee can determine how long his workers can be expected to work before rest breaks should be given. Workers have the right to and shoud immediately exit the hot environment prior to the time limit if they begin to experience heat stress symptoms.

8.2.4 If there are changes in the WBGT, the metabolic work load category, or the required clothing type during the course of the job, then a re evaluation of the job action time is necessary.

8.2.5 Absolute Stay Time will be two times the Recommended Action Time lAW Attachment 10.2 and EPRI guidelines.

AP-020 Rev. 16 Page 10 of 33

8.3 Determination of Recovery Period Times 8.3.1 When work cannot be completed in the estimated action time, the supervisor must calculate an appropriate recovery period for workers to dissipate excess heat and replace water. Recovery should take place in a cool location (less than 80 degrees F.) where drinking water or gatorade is available. The length of recovery period depends on the length of exposure and the action time of the job. Recovery periods of up to one hour may be necessary for jobs which approach or exceed the planned action times. The following formula should be used as a guide for determining the minimum length of recovery period. All times are in minutes.

REC= AET x 60 MST REC Recovery Time AET Actual Exposure Time to the Hot Environment MST Appropriate Action Time determined from Attachment 10.2 8.4 Use of Personal Cooling Devices CAUTION The personal cooling device should not be donned until just prior to entering the hot environment. The ice vest or Tube Suit will provide body cooling only while the ice is melting. Once the ice has melted, body temperature will increase quickly.

Workers should monitor their condition and exit the work area as soon as the ice vest has lost its cooling effectiveness.

8.4.1 By using Attachment 10.2, Recommended Heat Stress Control Action Times, the work crew leaders supervisor can determine if personal cooling devices would be beneficial for the job.

8.4.2 Individual workers should have the option of wearing a personal cooling device for any job when they feel there is a need. If a personal cooling device is worn, then the recommended action time is 60 minutes or until the ice melts.

AP-020 Rev. 16 Page 11 of 33

8.4 (Continued) 8.4.3 Ice vests are available in dressout areas in the Radiation Control Area.

8.4.4 The ice vest should be worn so that the vest fits snugly. A t-shirt should be worn under the vest.

8.4.5 Tube Suits are available in the Maintenance Shop.

CAUTION Use of supplied air hoods results in forced air cooling of the head, but not the body.

This can lead to a false sense of body cooling, and delayed awareness of heat stress by the hood user.

8.5 Use of Supplied Air Hoods 8.5.1 Supplied air hoods are used mainly as respirators and their uses are authorized only by the Radiation Control Unit.

8.5.2 When authorized for use, supplied air hoods will supply respirable air and cooling air to the head. Normal action times per Attachment 10.2 are applicable.

8.6 First Aid For Heat Illness 8.6.1 If any individual begins to feel symptoms of heat illness, then the person should immediately exit the area, notify the supervisor, rest in a cool area, and drink fluids. The Control Room (ext. 5555) should be called if symptoms persist.

8.6.2 Examples of symptoms that should necessitate calling the Control Room are as follows:

- Pulse rate does not decrease in 30-45 minutes

- Unconsciousness

- Cannot drink fluids without vomiting

- Heat stroke

- Any other symptom deemed to be of concern.

8.6.3 The individual in the Control Room who receives the call shall take appropriate actions to ensure further first aid and/or medical attention is provided.

AP-020 Rev. 16 Page 12 of 33

8.6.4 The following first aid actions should be taken at the first sign of heat stress symptoms.

1. Heat Illness occurs due to an increased body temperature and/or a loss of body fluids and salts.

First Aid Rest in cool area, drink water or other liquids to replace body fluids, and eat food high in salt content.

2. Heat Cramps are muscle spasms due to a loss of salt through sweating. Leg, stomach, and back muscles are most often affected and are often a sign of approaching heat exhaustion.

Cramps can also result from drinking large amounts of water without electrolytes (salt, sugar).

First Aid: Rest in cool area, drink water or other liquids, and eat food high in salt content.

3. Heat Exhaustion Condition caused by an insufficient flow of blood to the brain (blood is shunted to the skin to lose heat).

Symptoms can include cool, pale clammy skin, weakness, dizziness, headache, nausea, and fainting.

First Aid: Rest in cool area, lie down, elevate feet, apply cool wet cloths, fan with air, and drink liquids.

4. Heat Stroke a serious medical emergency caused by a failure of the bodys cooling mechanisms. Symptoms include hot, dry skin (sweating stops), extremely high body temperatures, strong, rapid pulse, and unconsciousness.

First Aid: Immediate, rapid cooling of the body is necessary. Use safety showers, move air over the body with a fan or by fanning, or cover the body with a wet sheet. Seek immediate medical attention.

AP-020 Rev. 16 Page 13 of 33

9.0 RECORDS N/A 10.0 ATTACHMENTS 10.1 Metabolic Heat Load Guidelines 10.2 Recommended Heat Stress Control Action Times 10.3 Heat Stress Evaluation Form 10.4 Estimating WBGT 10.5 Using the Wet Bulb Globe Thermometer 10.6 Heat Stress Pre-Job Briefing AP-020 Rev. 16 Page 14 of 33

ATTACHMENT 10.1 Page 1 of I METABOLIC HEAT LOAD GUIDELINES LIGHT WORK Light work are those average demands that are typical of job supervision, inspections, instrument repair and calibration, surveying. Light work can be performed indefinitely by everyone.

MODERATE WORK Moderate work are those average demands that are typical of a system walk-down, valve alignments, valve and motor repairs, and light materials handling. Under cool conditions, moderate work can be easily performed by most people if there is a 10-minute break every hour. Most physically demanding work falls into this category.

HEAVY WORK Heavy work are those average demands that are typical of gross decontamination, heavy materials handling, and extensive ladder and stair climbing. Even in comfortable conditions, heavy work can be sustained by most people for no more than 60 minutes.

It is not often that heavy work is the appropriate classification because rest breaks will reduce the overall demand to the moderate category.

AP-020 Rev. 16 Page 15 of 33

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ATTACHMENT 10.2 Page 2 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES CLOTH COVERALLS OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy NL NL NL 73 NL NL 240 74 NL NL 150 75 NL 240 120 76 NL 210 100 77 NL 165 90 78 NL 135 80 79 NL 110 70 80 240 95 65 81 230 85 55 82 215 80 50 83 200 70 45 84 180 65 40 85 165 55 40 86 150 50 35 87 130 50 35 88 115 45 30 89 110 40 25 90 100 40 25 91 90 35 20 92 85 35 20 93 75 35 20 94 65 30 20 95 60 30 15 96 55 25 PCR 97 50 25 PCR 98 50 25 PCR 99 45 25 PCR 100 40 20 PCR 101 35 20 PCR 102 30 20 PCR 103 30 20 PCR 104 25 20 PCR 105 25 15 PCR 106 25 15 PCR 107 25 PCR PCR 108 20 PCR PCR 109 20 PCR PCR 110 20 PCR PCR 111 20 PCR PCR 112 PCR PCR PCR 1 1________

NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 17 of 33

ATTACHMENT 1O2 Page 3 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES DOUBLE CLOTH COVERALLS (DC) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 69 NL NL NL 70 NL NL 240 71 NL NL 150 72 NL 240 120 73 NL 210 100 74 NL 165 90 75 NL 135 80 76 NL 110 70 77 240 95 65 78 230 85 55 79 215 80 50 80 200 70 45 81 180 65 40 82 165 55 40 83 150 50 35 84 130 50 35 85 115 45 30 86 110 40 25 87 100 40 25 88 90 35 20 89 85 35 20 90 75 35 20 91 65 30 20 92 60 30 15 93 55 25 PCR 94 50 25 PCR 95 50 25 PCR 96 45 25 PCR 97 40 20 PCR 98 35 20 PCR 99 30 20 PCR 100 30 20 PCR 101 25 20 PCR 102 25 15 PCR 103 25 15 PCR 104 25 PCR PCR 105 20 PCR PCR 106 20 PCR PCR 107 20 PCR PCR 108 20 PCR PCR 109 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 18 of 33

ATTACHMENT 10.2 Page 4 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES SCRUB SUIT OREX OVER SCRUB SUIT (CS) or SMS POLYPROPYLENE COVERALLS (PP) OVER (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 81 NL NL NL NL NL 240 82 83 NL NL 150 NL 240 120 84 NL 210 100 85 NL 165 90 86 NL 135 80 87 NL 110 70 88 240 95 65 89 230 85 55 90 215 80 50 91 200 70 45 92 180 65 40 93 165 55 40 94 150 50 35 95 130 50 35 96 115 45 30 97 98 110 40 25 100 40 25 99 90 35 20 100 85 35 20 101 75 35 20 102 65 30 20 103 60 30 15 104 55 25 PCR 105 50 25 PCR 106 50 25 PCR 107 45 25 PCR 108 40 20 PCR 109 35 20 PCR 110 30 20 PCR 111 30 20 PCR 112 25 20 PCR 113 25 15 PCR 114 25 15 PCR 115 25 PCR PCR 20 PCR PCR 117 20 PCR PCR 118 20 PCR PCR 119 20 PCR PCR 120 PCR PCR PCR 121 NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 19 of 33

ATTACHMENT 10.2 PageS of 11 RECOMME NDED HEAT STRESS CONTROL ACTION TIMES MB POLYETHYLENE COVERALLS (PE) (Tyvek 1422A) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 76 NL NL NL 77 NL NL 240 78 NL NL 150 79 NL 240 120 80 NL 210 100 81 NL 165 90 82 NL 135 80 83 NL 110 70 84 240 95 65 85 230 85 55 86 215 80 50 87 200 70 45 180 65 40 88 165 55 40 89 90 150 50 35 91 130 50 35 92 115 45 30 110 40 25 93 94 100 40 25 90 35 20 95 85 35 20 96 97 75 35 20 65 30 20 98 60 30 15 99 55 25 PCR 100 50 25 PCR 101 50 25 PCR 102 45 25 PCR 103 40 20 PCR 104 35 20 PCR 105 30 20 PCR 106 30 20 PCR 107 25 20 PCR 108 25 15 PCR 109 25 15 PCR 110 25 PCR PCR 111 20 PCR PCR 112 20 PCR PCR 113 20 PCR PCR 114 20 PCR PCR 115 PCR PCR PCR 116 NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 20 of 33

ATTACHMENT 10.2 Page 6 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES POLYESTER COVERALLS (P2) (ProTech 2000) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 76 NL NL NL 77 NL NL 240 NL NL 150 78 79 NL 240 120 80 NL 210 100 81 NL 165 90 NL 135 80 82 NL 110 70 83 240 95 65 84 230 85 55 85 215 80 50 86 200 70 45 87 88 180 65 40 165 55 40 89 150 50 35 90 130 50 35 91 115 45 30 92 110 40 25 93 100 40 25 94 95 90 35 20 85 35 20 96 75 35 20 97 65 30 20 98 99 60 30 15 55 25 PCR 100 50 25 PCR 101 50 25 PCR 102 45 25 PCR 103 40 20 PCR 104 35 20 PCR 105 30 20 PCR 106 30 20 PCR 107 25 20 PCR 108 109 25 15 PCR 25 15 PCR 110 25 PCR PCR 111 20 PCR PCR 112 20 PCR PCR 113 20 PCR PCR 114 20 PCR PCR 115 PCR PCR PCR 116 NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 21 of 33

ATTACHMENT 10.2 Page 7 of 11 RECOMME NDED HEAT STRESS CONTROL ACTION TIMES WATER-BARRIER, VAPOR-PERMEABLE COVERALLS (WB-1) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 68 NL NL NL 69 NL NL 240 70 NL NL 150 71 NL 240 120 72 NL 210 100 73 NL 165 90 74 NL 135 80 75 NL 110 70 76 240 95 65 77 230 85 55 78 215 80 50 79 200 70 45 80 180 65 40 81 165 55 40 82 150 50 35 83 130 50 35 84 115 45 30 85 110 40 25 86 100 40 25 87 90 35 20 88 85 35 20 89 75 35 20 90 65 30 20 91 60 30 15 55 25 PCR 92 93 50 25 PCR 94 50 25 PCR 45 25 PCR 95 96 40 20 PCR 35 20 PCR 97 30 20 PCR 98 30 20 PCR 99 100 25 20 PCR 25 15 PCR 101 25 15 PCR 102 25 PCR PCR 103 20 PCR PCR 104 20 PCR PCR 105 20 PCR PCR 106 20 PCR PCR 107 PCR PCR PCR 108 NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 22 of 33

ATTACHMENT 10.2 Page 8 of Ii RECOMMENDED HEAT STRESS CONTROL ACTION TIMES WATER-BARRIER VAPOR-PERMEABLE COVERALLS (WB-2) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 74 NL NL NL 75 NL NL 240 76 NL NL 150 77 NL 240 120 78 NL 210 100 79 NL 165 90 80 NL 135 80 81 NL 110 70 82 240 95 65 83 230 85 55 84 215 80 50 85 200 70 45 86 180 65 40 87 165 55 40 88 150 50 35 89 130 50 35 90 115 45 30 91 110 40 25 92 100 40 25 93 90 35 20 94 85 35 20 95 75 35 20 96 65 30 20 97 60 30 15 98 55 25 PCR 99 50 25 PCR 100 50 25 PCR 101 45 25 PCR 102 40 20 PCR 103 35 20 PCR 104 30 20 PCR 105 30 20 PCR 106 25 20 PCR 107 25 15 PCR 108 25 15 PCR 109 25 PCR PCR 110 20 PCR PCR 111 20 PCR PCR 112 20 PCR PCR 113 20 PCR PCR 114 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 23 of 33

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ATTACHMENT 10.2 Page 10 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES ENCAPSULATING SUIT OR TURN-OUT GEAR (ES) OVER SCRUB SUIT (CS)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 62 NL NL NL 63 NL NL 240 64 NL NL 150 65 NL 240 120 66 NL 210 100 67 NL 165 90 68 NL 135 80 69 NL 110 70 70 240 95 65 71 230 85 55 72 215 80 50 73 200 70 45 74 180 65 40 75 165 55 40 76 150 50 35 77 130 50 35 78 115 45 30 79 110 40 25 80 100 40 25 81 90 35 20

82 85 35 20 83 75 35 20 84 65 30 20 85 60 30 15 86 55 25 PCR 87 50 25 PCR 88 50 25 PCR 89 45 25 PCR 90 40 20 PCR 91 35 20 PCR 92 30 20 PCR 93 30 20 PCR 94 25 20 PCR 95 25 15 PCR 96 25 15 PCR 97 25 PCR PCR 98 20 PCR PCR 99 20 PCR PCR 100 20 PCR PCR 101 20 PCR PCR 102 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 25 of 33

ATTACHMENT 1O2 Page 11 of 11 RECOMMENDED HEAT STRESS CONTROL ACTION TIMES FLAME RETARDANT SHIRT AND PANTS (FR)

WBGT METABOLIC HEAT LOAD and ACTION TIMES IN MINUTES degrees F Light Moderate Heavy 79 NL NL NL 80 NL NL 240 81 NL NL 150 82 NL 240 120 83 NL 210 100 84 NL 165 90 85 NL 135 80 86 NL 110 70 87 240 95 65 88 230 85 55 89 215 80 50 90 200 70 45 91 180 65 40 92 165 55 40 93 150 50 35 94 130 50 35 95 115 45 30 96 110 40 25 97 100 40 25 98 90 35 20 99 85 35 20 100 75 35 20 101 65 30 20 102 60 30 15 103 55 25 PCR 104 50 25 PCR 105 50 25 PCR 106 45 25 PCR 107 40 20 PCR 108 35 20 PCR 109 30 20 PCR 110 30 20 PCR 111 25 20 PCR 112 25 15 PCR 113 25 15 PCR 114 25 PCR PCR 115 20 PCR PCR 116 20 PCR PCR 117 20 PCR PCR 118 20 PCR PCR 119 PCR PCR PCR NOTES: NL = No Limit, PCR = Personal Cooling Required (refer to 8.4.2)

AP-020 Rev. 16 Page 26 of 33

ATTACHMENT 10.3 Page 1 of 1 HEAT STRESS EVALUATION FORM JOB DATE:

JOB LOCATION:

TASK(S):

SUPERVISOR:

EST. PERSON-HOURS:

NUMBER OF WORKERS:

PLANT STATUS (for job planning use):

CLOTHING TYPE:

METABOLIC HEAT LOAD (CIRCLE ONE):

LIGHT MODERATE HEAVY TEMPERATURE (CIRCLE ONE):

MEASUREMENT ESTIMATE WBGT=

DB= WB= GT=

ACTION TIME = minutes (from Attachment 10.2)

RECOVERY PERIOD = minutes = (Time in minutes in Hot Environment) x (60)

(Action Time in minutes)

HAVE WORKERS RECEIVED A PRE-JOB BRIEFING INCLUDING HEAT STRESS CONCERNS?

(CIRCLE ONE)

YES NO ADDITIONAL INFORMATION:

Signature (Job Supervisor): Date:

AP-020 Rev. 16 Page 27 of 33

ATTACHMENT 10.4 Page 1 of 1 ESTIMATING WBGT Measuring WBGT may require entering the work area prior to the start of the job.

However, this action could also create an ALARA concern.

There are two methods which can be used to estimate the WBGT without entering the work area.

The first method is to estimate the WBGT based on previously recorded measurements, such as those obtained from the Heat Stress Evaluation Form (Attachment 10.3). The plant condition and work location must be essentially identical to use this method.

NOTE: The following method may underestimate the actual WBGT for work performed directly adjacent to hot steam pipes or other radiant heat sources.

The second method is based on a remote reading of the dry bulb temperature (DB) and an estimation of the relative humidity as follows: (When the relative humidity is not known, use 100% value for estimation)

RELATIVE HUMIDITY ESTIMATED WBGT 100% DB+4°F 90% DB + 2°F 80% DB 70% DB-3°F 60% DB-5°F 50% DB-7°F 40% DB 9°F AP-020 Rev. 16 Page 28 of 33

ATTACHMENT 10.5 Page 1 of I USING THE WET BULB GLOBE THERMOMETER Measuring WBGT by using the Wet Bulb Globe thermometer will require enterin g

the work area prior to the start of the job. Be sure to prepare the meter for use, prior to bringing it into the hot environment, in order to save time.

To prepare the meter:

1. Connect each of the wet bulb, dry bulb, and globe sensors to the unit. Look at the symbols located on the top of the unit to determine the appropriate connector for each sensor. Use caution to insure that the connector prongs are aligned properly in order to avoid damaging the sensors.

2. Use distilled water to saturate the sponge and wick on the wet bulb sensor.

To operate the meter:

1. Turn the meter on to the desired function; WBGT in for indoor measurements, or WBGT out for outdoor measurements.

2. Allow the sensors to stabilize in the environment where reading is being taken. Typical response times may be as long as 15 minutes.

3. Take reading once display has stabilized.

Changing Batteries/Meter Calibration:

1. Consult owners manual.

AP-020 Rev. 16 Page 29 of 33

ATTACHMENT 10.6 Page 1 of 1 HEAT STRESS PRE-JOB BRIEFING Advise persons entering a heat stress area of the recommended action time and the absolute stay time.

Advise persons entering a heat stress area of any required engineering controls or of any personal cooling device requirements, such as ice vests or Tube Suits.

Advise persons entering a heat stress area:

They may become dehydrated due to sweating.

Lost body water and electrolytes should be replaced by drinking during rest breaks to prevent heat-related illness.

Where they may obtain drinking water and/or Gatorade.

Where cooler rest areas are located and the duration of minimum recovery times.

First Aid for Heat Stress:

Heat Cramps are muscle spasms due to a loss of salt through sweating. Leg, stomach, and back muscles are most often affected and are often a sign of approaching heat exhaustion. Cramps can also result from drinking large amounts of water without electrolytes (salt, sugar).

First Aid: Rest in cool area, drink water or Gatorade, and eat food high in salt content.

Heat Exhaustion Condition caused by an insufficient flow of blood to the brain (blood is shunted to the skin to lose heat). Symptoms can include cool, pale clammy skin, weakness, dizziness, headache, nausea, and fainting.

First Aid: Rest in cool area, lie down, elevate feet, apply cool wet cloths, fan with air, and drink liquids.

Heat Stroke a serious medical emergency caused by a failure of the bodys cooling mechanisms. Symptoms include hot, dry skin (sweating stops), extremely high body temperatures, strong, rapid pulse, and unconsciousness.

First Aid: Immediate, rapid cooling of the body is necessary. Use safety showers, move air over the body with a fan or by fanning, or cover the body with a wet sheet.

Seek immediate medical attention.

AP-020 Rev. 16 Page 30 of 33

ATTACHMENT 10.7 Page 1 of 3 DEFINITIONS

Absolute Stay Time Two times the Recommended Action Time (lAW Attachment 10.2 and EPRI guidelines)

Acclimation The gradual process of improved heat tolerance after continuous exposure to heat. Acclimation consists of reduced heart rate, increased sweat production, production of less salty sweat, and lower body temperature.

Action Time An estimate of the length of time workers may be exposed in hot environments without personal cooling devices and not suffer heat stress disorders (used for planning purposes). The length of action times is not absolute because of worker variability in response to heat.

ALARA (As Low As Reasonably Achievable) Making every reasonable effort to maintain exposure to radiation as far below the dose limits as is practical, taking into account the state of technology, and the economics of improvements in relation to the benefits.

Cloth Coveralls (CC) A standard configuration of anticontamination coveralls with a hood and hand and foot coverings. The fabric is either a cotton or cotton/polyester blend with weights of about 8 to 9 oz/sqyd.

Cloth Coveralls over Scrub Suit (CS) The configuration described as CC plus a set of 2 oz/sqyd cloth underalls (a.k.a. surgical scrub suit).

Double Cloth Coveralls (DC) The configuration described as CC plus a second set of cloth coveralls only.

Dry Bulb Temperature (DB) The temperature as measured by a standard thermometer, without respect to humidity or radiant heat.

Encapsulating Suit or Turn-out Gear (ES) Total encapsulating suits (eg, Level A); re-usable, whole body chemical protective suits; firefighter turn-out gear.

Flame-Retardant Shirt and Pants (FR) - Long-sleeve shirt and pants made from a treated cotton fabric.

Globe Temperature (GT) Temperature resulting from radiant heat sources, measured with a globe thermometer.

Globe Thermometer A thermometer with a black globe at its end, used for measuring radiant heat.

AP-020 Rev. 16 Page 31 of 33

ATTACHMENT 10.7 Page 2 of 3 DEFINITIONS (Continued)

Heat Stress The physiological stress which occurs when the body temperature rises above normal. This occurs when the body produces or gains more heat than it is capable of losing. It is caused by any combination of air temperature, thermal radiation, humidity, air flow, restrictive clothing, and physical work load which may result in elevated core body temperature and subsequent illness.

High Heat Stress Job/Work Any job or work in which the calculated action time, without regard to personal cooling equipment, is less than 30 minutes.

MB Polyethylene Coveralls (PE) Limited use coveralls with hood (particle barrier only) made from a meltblown polyethylene (Tyvek 1422A).

Metabolic Heat Load Heat generated by the body, which increases with physical work. Examples may be found on Attachment 10.1.

Moderate Heat Stress Job/Work Any job/work in which the calculated action time, without regard to personal cooling equipment, is greater than 30 minutes but less than 240 minutes.

OREX Disposable coveralls made of poly vinyl alcohol (PVA).

Personal Cooling Device Equipment such as ice vests or Tube Suits, used to minimize heat gain and/or increase heat loss.

Polyester Coveralls (P2) Light-weight polyester (98% nylon)(3 oz/sqyd) coveralls worn with a hood of the same material (ProTech 2000).

Polyester Coveralls with Scrubs (PS) Light-weight polyester coveralls and hood (P2) worn over a typical surgical scrub suit (cotton or cotton/polyester blend).

Protective Clothing Items worn to prevent radioactive contamination.

Recovery Period Time allowed to be spent outside of a hot area allocated to workers who have performed work in hot environments. Water or gatorade should be available for consumption in the recovery area.

Relative Humidity The amount of moisture in the air compared to the amount of moisture the air can hold for a given temperature.

Self Determination Allowing for worker discretion to exit Heat Stress Work Areas.

AP-020 Rev. 16 Page 32 of 33

ATTACHMENT 10.7 Page 3 of 3 DEFINITIONS (Continued)

SMS Polypropylene Coveralls (PP) Limited-use coveralls with hood (particle barrier only) made from a spunbonded, meltblown polypropylene.

Supplied Air Hood Air-supplied hood respirator which will deliver respirable air over the head and upper body.

Vapor-Barrier Coveralls (VB) Coveralls and hood made of light weight fabrics designed for limited use. Typical fabrics might be a polyethylene coated spunbonded polyethylene or a polyvinylchloride.

Water-Barrier, Vapor Permeable Coveralls (WB-1) Limited-use coverall with hood made from tn-laminate fabric with a tetrafluoroethylene microporous film.

Water-Barrier, Vapor Permeable Coveralls (WB-2) Coverall with hood made from tn-laminate fabric with a microporous film.

Wet-Bulb Temperature (WB) The temperature as determined by a wet bulb thermometer. This temperature is influenced by the evaporation rate of water, which is dependent upon the relative humidity in air.

Wet-Bulb Globe Temperature (WBGT) An index of heat-stress based on globe, dry and wet bulb temperatures.

Wet-Bulb Globe Thermometer A thermometer with sensors to measure wet bulb, dry bulb, and globe temperatures.

Work Clothes (WC) A standard ensemble that includes a 4 oz/sqyd cotton shirt with long sleeves and 8 oz/sqyd cotton pants.

AP-020 Rev. 16 Page 33 of 33

Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 02344101203 Task

Title:

Complete Equipment Inoperable JPM No.: 2011-2 NRC JPM Admin Record SROA1-2 K/A

Reference:

G2.1 18 (3.6/3.8)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

Unit operating at 100% RTP steady state

CCW Pump B removed from service at 1245 hours0.0144 days 0.346 hours 0.00206 weeks 4.737225e-4 months on 12/i/il due to failed inboard motor bearing

No additional equipment is inoperable

Current plans will return to service in 44 hours5.092593e-4 days 0.0122 hours 7.275132e-5 weeks 1.6742e-5 months

Work order # 47548629 has been initiated

NCR # 407627 has been initiated Task Standard: Complete OMM-007, Attachment 10.1 and 10.11 Required Materials: OMM-007, Equipment Inoperable Record, Rev. 85 PLP-100, Technical Requirements Manual, Rev. 36 General

References:

OMM-007, Equipment Inoperable Record, Rev. 85 Handouts: OMM-007, Equipment Inoperable Record, Rev. 85 PLP-100, Technical Requirements Manual, Rev. 36 2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Initiating Cue: The CRS has directed you to complete the necessary OMM-007 attachment(s) for the inoperability of COW Pump B Another SRO will perform the checklist of OMM-OOi-8, Control of Equipment and System Status and OPS-NGGC-i 000, Fleet Conduct of Operations.

All necessary outside notifications will be made by the Shift Manager.

Time Critical Task: NO Validation Time: 30 minutes 2011-2 NRC JPM Admin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of 15 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk )

Start Time:

NOTE: Completion of EIR Ultimate Heat Sink (UHS) for Service Water Temperature Exceeding 97°F will be used versus this section if entering ITS LCO 3.7.8 (UHS) REQUIRED ACTIONS due to Service Water temperature exceeding 97°F.

Performance Step: I Perform the Revision Verification (Step 8.2.1)

Standard: Candidate performs the revision verification or states that he uses the Control Room copy, enters todays date and initials on Attachment 10.1, EIR ITSITRM/ODCM/RG 1.97.

Examiners Note:

Examiners Cue: Revision verification is the correct revision.

Comment:

Performance Step: 2 Enter the name of the equipment which is inoperable in Section A (Step 8.2.2)

Standard: Candidate enters CCW Pump B in Section A.

Examiners Note:

Comment:

2011-2 NRC JPM Admin SROAI-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 3 Record the reason for the equipment inoperability. This may include MOD number, problems with the equipment, and/or work to be performed (Step 8.2.3)

Standard: Candidate documents that motor bearing failure is the reason for the inoperability.

Examiners Note:

Comment:

Performance Step: 4 Verify a Work Request has been initiated (if applicable) AND record the WR number (ACR 94-00281) (Step 8.2.4)

Standard: Candidate documents a work request number and fills in the WR

blank.

Examiners Note:

Comment:

2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 15 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 5 IF the unavailability is unplanned, AND the component is part of a system listed on Attachment 10.10, THEN review OMM-048 AND the Maintenance Rule Scoping and Performance Criteria basis section of the Maintenance Rule Database to determine if the listed function(s) of the system is/are affected.

IF a system function is affected, THEN initiate a CR stating a potential Safety Significant Functional Failure has occurred lAW OMM-048, and record the CR# in Section D (Step 8.2.5)

Standard: Candidate determines that the unavailability is unplanned and the component is listed in Attachment 10.10. A CR number is recorded in the blank under Section D.

Examiners Note: Attachment 10.10, Maintenance Rule Systems, lists System

4080, Component!Cooling Water System to be considered a High Safety Significant System under the Maintenance Rule.

Comment:

Performance Step: 6 Complete Section E as follows:

Item 1 Enter the TIME AND DATE that the equipment was declared inoperable (Step 8.2.6)

Standard: Candidate enters the TIME as 1245 and DATE as 1211111.

Examiners Note:

Comment:

2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 15 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 7 Complete Section E as follows:

Item 2 Circle the applicable document abbreviation and enter applicable LCD, TRMS or Specification number. Be specific. For example, provide table number and item number where applicable.(Step 8.2.6)

Standard: Candidate circles ITS and enters LCO 3.7.6, Condition A.

Examiners Note:

Comment:

Performance Step: 8 Complete Section E as follows:

Item 3 Enter any applicable actions required to satisfy the document identified in Item 2 and any required completion time. (Step 8.2.6)

Standard: Candidate enters as follows: Restore required CCW Train to operable status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . THEN apply Condition B Be in Mode 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and Mode 5 in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

Examiners Note:

Comment:

2011-2 NRC JPM Admin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 15 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 9 Complete Section E as follows:

Item 4 Enter the maximum time the equipment is allowed to be inoperable in the applicable blank. Circle hrs/days as they apply to the Special Report. (Step 8.2.6)

Standard: Candidate enters 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months in the MODE 3 blank and 108 hours0.00125 days 0.03 hours 1.785714e-4 weeks 4.1094e-5 months in the MODE 5 blank.

Examiners Note:

Comment:

Performance Step: 10 Complete Section E as follows:

Item 5 Enter the Time and Date that ltem4 is required in the applicable blank. (Step 8.2.6)

Standard: Candidate enters 1845 in the Time blank and 1214111 in the Date blank for MODE 3.

Candidate enters 0045 in the Time blank and 1216/11 in the Date blank for MODE 5.

Examiners Note:

Comment:

NOTE: ODCM required initial compensatory samples lack a grace period.

2011-2 NRC JPM Admin SRO Ai-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 11 Complete Section E as follows:

Item 6 Enter any applicable surveillances or activities and required frequencies which are required as a result of the component noperability. (Step 8.2.6)

Standard: Candidate enters NONE.

Examiners Note:

Comment:

2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement i

Appendix C Page 9 of 15 Form ES-c-i PERFORMANCE INFORMATION Performance Step: 12 IF the component is an ITS Support System component, THEN perform Attachment 10.11, which is provided to ensure Safety Function Determinations are performed consistently. The TRM contains in-depth guidance for performing Safety Function Determinations. [CAPR 193057] (Step 8.2.7) (Attachment 10.1, Section F)

Standard: Candidate determines the following from Attachment 10.11, Loss of Safety Function Worksheet, Page 1 of 4:

1. TS Support Feature is Inoperable Yes, CCW Pump B.

2. Determine the impact the inoperability has on applicable supported systems.

3. Does the TS support feature result in a supported feature LCD not met NO

4. Exit the SFDP.

Attachment 10.11, Page 2 of 4 completed as follows:

Revision status checked with Date and INIT filled in.

Date of 1211111 and Time of 1245 completed MODEl, Power 100%, RCS Temperature - 575.9°F, RCS Pressure 2235 psig.

1) List inoperable ITS Support Feature: CCW Pump B listed and step initialed.

2) IF inoperable ITS Support Feature does NOT result in ITS Supported Feature inoperability, THEN perform the following:

a) N/A Steps 3 through 8 and step initialed.

b) Sign and Date and step initialed.

Examiners Note:

Corn rnent:

2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 15 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 13 IF the component is an ITS Supported System Component, THEN review open Loss of Safety Function Worksheets (Attachment 10.11) for impact AND log in AUTO log to document review. [CAPR 193057] (Step 8.2.8) (Attachment 10.1, Section G)

Standard: Candidate determines that there are no open Loss of Safety Function worksheets.

Examiners Note:

Comment:

Performance Step: 14 Initial the blank in Section H when the Load Dispatcher has been notified when the component inoperability could force plant shutdown or load reduction. [SOER 99-1. Rec. 1C] (Step 8.2.9)

Standard: Candidate initials blank for Load Dispatcher notification.

Examiners Cue: If requested, respond as the Load Dispatcher that notification has been received.

Comment:

Performance Step: 15 Initial the blank in Section 1 when Planning and Scheduling has been notified when ITSITRM/ODCM/RG 1.97 actions have been entered and plant shutdown is anticipated. (Step 8.2.10)

Standard: Candidate initials the blank that Planning and Scheduling has been notified of anticipated plant shutdown.

Examiners Cue: If requested, respond as Planning and Scheduling that notification has been received.

Comment:

2011-2 NRC JPM Admin SRO Ai-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 11 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 16 IF the EIR is completed due to a Radiation Monitor, Flowrate Monitor or Tank Level Monitor inoperability, THEN enter the E&C Technicians name, time and date of notification in the blanks in Section J. (Step 8.2.11)

Standard: Candidate determines that the component inoperability does not involve any radiation monitor, flowrate monitor or tank level monitor and N/As the blanks in Section J of Attachment 10.1.

Examiners Note:

Comment:

NOTE: Maintenance Rule data can be found by clicking on Start, Programs, Engineering, RNP, and RNP System Notebook. When the database opens move the desired system(s) from the list of available systems to the list of selected systems. From the list of Systems Notebook links click on M.R. System Specific Reports, then click on Performance Summary.

2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 12 of 15 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 17 IF a Maintenance Rule System monitored for unavailability (Attachment 10.10, page 2) is affected, THEN record the Allowed Unavailability hours, subtract the actual unavailability hours, and record the remaining unavailability hours in Section K. (NCR 102997) (Step 8.2.12)

Standard: Candidate determines that System 4080-CCW, CCW Pump Trains is listed in Attachment 10.10, Page 2.

Candidate determines that the Allowed Unavailability hours is 132 hours0.00153 days 0.0367 hours 2.18254e-4 weeks 5.0226e-5 months , the actual unavailability hours is 94.25 hours2.893519e-4 days 0.00694 hours 4.133598e-5 weeks 9.5125e-6 months and the remaining unavailability hours is 38 hours4.398148e-4 days 0.0106 hours 6.283069e-5 weeks 1.4459e-5 months .

132 Hours Allowed 94.25 Hours Actual = 38 Hours Remaining will be entered in Section K of Attachment 10.1.

(Allowable band of 37.75 to 38.0 unavailability hours remaining)

Data will be provided to the candidate from the Maintenance Examiner s Note:

Rule Database.

Comment:

Performance Step: 18 IF the unavailability is unplanned and remaining unavailability hours are less the 72, THEN notify the RES Duty Manager and record the name, date, and time in Section K. (NCR 102997)

(Step 8.2.13)

Standard: Candidate determines that the remaining hours is less than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and notifies the RES Duty Manager. He documents the name, date and time that the notification was made.

Examiners Note:

Comment:

2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 13 of 15 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 19 The SM OR the CRS shall review the EIR AND sign AND date following completion in Section L. (Step 8.2.14)

Standard: Candidate will sign and date the Completed By portion of Attachment 10.1, Section L.

Examiners Note:

Comment:

Performance Step: 20 The comments section is used for documenting failed testing or changed equipment status. (Step 8.2.15)

Standard: Candidate can place any comments needed or mark the comments as N/A or NONE.

Examiners Note:

Comment:

END OF TASK Termination Cue: EIR completion for the CCW Pump B inoperability completes the JPM.

STOP TIME:

2011-2 NRC JPM Admin SRO A1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 14 of 15 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM Admin SRO A1-2 Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement 1

1(7 ATTACHMENT 10.1 Page 1 of 2 EIR - ITSITRMIODCMIRG 1.97 CONTINUOUS USE This revision has been verified to be the latest revision available.

Date I NW A. Equipment Inoperable: teto 7 1

9 ,(4J; 4 B. Reason for Equipment Inoperability:

/ //-? té /iJA&4t( 4 b4Cj A1t27 C. WR initiated: (ACR 94-00281) WR # 7/2 2_/

D. IF an unplanned unavailability AND a High Safety Significant Maintenance Rule System FUNCTION is affected by the equipment, THEN initiate CR stating a potential a.

significant functional failure has occurred.

E. Operating Limitations:

CR #

7

,/

1. Equipment declared inoperable: Time Date /2/( /(

2. FRM/ODCM/RG I .97Other reference number L1t2 3 L

7 L, JdiZ7it 4 14 Circle one)

3. actions a 7 associa d completion tim 7 1

ff

/w/ AfJ her 4.

Maximum time equipment allowed inoperaDie berore:

6 &i A1Cd MODE 2 Hrs MODE 3Hrs MODE4 Hrs MODE 54f-1rs _3 %et Special Report hrs/days

5. Time AND Date Action Required:

MODE 2 Time: Date:

MODE 3 Time: Date: /2/

f 1 fI MODE 4 Time: Date:

MODE 5 4 2

Time:t Date:

Special Report Time: Date:

6. Record any surveillance required to be performed as a result of the inoperability of this compo,nent (ODCM initial compensatory samples lack a grace period.)

Al OMM-007 Rev. 85 Page 31 of 88

ATTACHMENT 10.1 Page 2 of 2 EIR ITS!TRMIODCM!RG 1.97 F. IF this is an ITS Support System Component, THEN perform Attachment 10.11.

[CAPR 193057]

G. IF this is an ITS Supported System Component, THEN review open Loss of Safety Function Worksheets (Attachment 10.11) for impact.

H. Load Dispatr-r4ffjpd of REQUIRED ACTION which could force plant shutdown/load reduction. (SM/CRS Initials) [SOER 99-1, Rec. IC]

I. Planning Sand Scheduling notified to develop Forced Outage Schedule if ITS/TM5DJCM/RG 1.97 actions are entered AND plant shutdown anticipated.

_-_f/2L.--i (SM/CRS Initials)

J. IF this EIR is for a Radiation Monitor, Flowrate Monitor or Tank Level Monitor, THEN notify E&C of equipmeflt inoperability:

Time ,J (A Date______ ,J IA E&C Shift Technician (Print name)

K. IF a Maintenance Rule System Function is affected, THEN record Allowed Unavailability Hour Actual Unavailability,-1ours, and Unavailability Hours Remaining.

/5Hours Allowed - llours Actual = Hours Remaining IF unpla,nned and less than 72 Hours remaining, THEN notify the RES Duty Manager.

Name D&te 1 ,Tim L. Completed By:

SM/CRS D te M. Comments:

N. Restoration

1. Equipment operable: Time Date

2. IF this EIR is for a Radiation Monitor, Flowrate Monitor or Tank Level Monitor, THEN notify E&C of equipment return to service:

Time Date E&C Shift Technician (Print Name)

3. Equipment no longer required due to plant conditions:

Time Date Reason:

4. Completed By:

SM/CRS Date OMM-007 Rev. 85 Page 32 of 88

ATTACHMENT 10.10 Page 1 of 2 MAINTENANCE RULE SYSTEMS INFORMATION USE The following systems are considered to be High Safety Significant Systems under the Maintenance rule.

1000 Containment lsol Valve Pseudo 5098 Dedicated Shutdown Diesel Generator System 1005 Reactor Vessel and Internals System 5100 Fuel Oil System 1045 Excore Nuclear Instrument System 5114 Dedicated Shutdown System 1065 Rod Control System 5120 Switchyard and Transformer System 1080 Reactor Protection and Safeguards 5170 4 K\ AC Distribution System System 2005 Reactor Coolant System 5175 480V AC Distribution System 2045 Residual Heat Removal System 5185 208-1 20 VAC Distribution System 2060 Chemical and Volume Control System 5235 125V DC Battery/Charger/Distribution System 2080 Safety Injection System 6135 Instrument Air System 3005 Steam Generator 6150 Nitrogen Supply/Blanketing System 3020 Main Steam 6175 Site Fire Protection System 3050 Feedwater System 6270 Primary and Demineralized Water Makeup System 3065 Auxiliary Feedwater 8010 Containment System 3070 Condensate System 8150 HVAC Containment Building System 4060 Service Water System 8210 HVAC Auxiliary Building

( 4080 Component/Cooling Water System ) 8220 HVAC Control Room Area 5095 Emergency Diesel Generator System OMM-007 Rev. 85 Page 55 of 88

ATTACHMENT 1O10 Page 2 of 2 MAINTENANCE RULE SYSTEMS The following systems require unavailability monitoring for the maintenance rule:

System Whats Monitored 1065 Rod Drive Reactor trip breakers 2005 RCS RCS PORVs and block valves 2045 RHR RHR trains 2060 CVCS Charging pump trains, boric acid pumps, emergency boration flowpath 2080 SI SI Pump trains, CV Spray trains, Accumulators 3020 MS S/G PORVs, Steam Supplies to SDAFW 3065 AFW AFW Pump trains, injection lines 4060 SW SW pumps, SW booster pumps, north and south headers, Turbine Building lsotion C ioo ccy) c pump train)heat exchangers 5095 EDG EDG trains 5098 DSDG Dedicated Shutdown Diesel 5114 DS DS bus, DS-UPS-lnverter 51704KV Auto Bus Transfer breakers 5175480 V Bus E-1, Bus E-2 5185 120/ 208 VAC Constant voltage transformers 5235 125 VDC Battery Chargers, lnverters, DC Buses 6004 ERFIS ERFIS Computer 6135 IA Compressors, Backup Air Supply For Charging Pumps 6175 FP Pumps, Flowpath to SI, AFW, CVCS Pump cooling / suction 6270 Primary Water Deep Well Pump D, Primary Water Pumps and Header 8150 CV HVAC HVH units 8220 MCR HVAC Ventilation fans, Emergency Filtration Unit, Control Room Envelope Integrity OMM-007 Rev. 85 Page 56 of 88

ATTACHMENT 10.11 Page 1 of4 LOSS OF SAFETY FUNCTION WORKSHEET

[CAPR 193057]

CONTINUOUS USE NOTE: The numbers in the flow chart correspond to the description of SFD steps in Appendix C of the TRM.

OMM-007 Rev. 85 Page 57 of 88

ATTACHMENT 10.11 Page 2 of 4 LOSS OF SAFETY FUNCTION WORKSHEET This revision has been verified to be the latest revision available. /2 1

1 /ti lIa e Date:___________ Plant Conditions Time: (1.

MODE Power RCS Temperature RCS Pressure (CO &4 Z NOTE: This Safety Function Determination should be performed by a licensed Senior Reactor Operator and should be reviewed any time additional inoperabilities occur or an ITS Supported Feature is declared inoperable.

1) List inoperable ITS Support Featur (ci) /,A

2) IF inoperable ITS Support Feature does NOT result in ITS Supported Feature inoperability, THEN perform the following:

a) N/A steps 3 through 8.

b) Sign and date.

c) Forward worksheet to SM for review.

d) IF the Support Feature will NOT be returned to service prior to end of shift, THEN attach completed worksheet to the EIR for the Support Feature.

e) IF the Support Feature will be returned to service prior to end of shift, THEN file LOSF Worksheet in EIR notebook.

3) IF inoperable ITS Support Feature results in ITS Supported Feature inoperability, THEN list inoperable ITS Sppported Feature(s).

Al/A OMM-007 Rev. 85 Page 58 of 88

ATTACHMENT 10.11 Page 3 of 4 LOSS OF SAFETY FUNCTION WORKSHEET I NIT

4) IF support feature ITS Actions require cascading to Supported Feature(s) ITS Actions, THEN perform the following:

a) Enter applicable ITS Actions of Supported Feature(s) ITS.

b) N/Asteps5through8.

c) Sign and date.

d) Forward worksheet to SM for review.

e) Attach completed worksheet to the EIR for the Support Feature. !44

5) IF any other ITS LCOs are NOT met, THEN determine the impact the inoperabilities have on all applicable Suort yeatures AND list.

7

6) IF there are NO redundant Supported Features inoperable, THEN perform the following:

a) N/Asteps7and8.

b) Sign and date.

c) Forward worksheet to SM for review.

d) Attach completed worksheet to the EIR for the Supported Feature.

7) IF a LOSF does NOT exist for the Supported Feature ITS, THEN perform the following:

a) Calculate and record the maximum completion time to restore the ITS Support Feature n associated ITS Supporte Feature(s) to operable tatus.

1 s t Support Feature Supported Feature A)/A Max Completion hrs b) N/Astep8. ill/leg.

c) Sign and date. 4J/4 d) Forward worksheet to SM for review.

e) Attach completed worksheet to the EIR for the Supported Feature.

OMM-007 Rev. 85 Page 59 of 88

ATTACHMENT 10.11 Page 4 of 4 LOSS OF SAFETY FUNCTION WORKSHEET INIT

8) IF a LOSF exists for the Supported Feature ITS, THEN perform the following:

a) Calculate and record the maximum completion time to restore the ITS Support Feature ii associated ITS Support Feature(s) to operabl status.

st 1

IJ)k Suppo Feature hrs +

Supported Feature hrs = ,V 74 Max Completion h rs b) Enter the applicable ITS LCO for the ITS Supported Feature or ITS LCO 3.0.3 as applicable.

c) Attach completed worksheet to the EIR for the Supported Feature.

Remarks:

44 Completed By: Date: z/i (If SRO Reviewed By: Date:

SM J OMM-007 Rev. 85 Page 60 of 88

Appendix C Page 15 of 15 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

Unit operating at 100% RTP

CCW Pump B removed from service at 1245 hours0.0144 days 0.346 hours 0.00206 weeks 4.737225e-4 months on 12/i/li due to failed inboard motor bearing

No additional equipment is inoperable

Current plans will return to service in 44 hours5.092593e-4 days 0.0122 hours 7.275132e-5 weeks 1.6742e-5 months

Work order # 47548629 has been initiated

NCR # 407627 has been initiated INITIATING CUE: The CRS has directed you to complete the necessary OMM-007 attachment(s) for the inoperability of CCW Pump B Another SRO will perform the checklist of OMM-001-8, Control of Equipment and System Status and OPS-NGGC-1 000, Fleet Conduct of Operations.

All necessary outside notifications will be made by the Shift Manager.

2011-2 NRC JPM Admin SROA1-2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 15 of 15 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

Unit operating at 100% RTP

CCW Pump B removed from service at 1245 hours0.0144 days 0.346 hours 0.00206 weeks 4.737225e-4 months on 12/1/11 due to failed inboard motor bearing

No additional equipment is inoperable

Current plans will return to service in 44 hours5.092593e-4 days 0.0122 hours 7.275132e-5 weeks 1.6742e-5 months

Work order # 47548629 has been initiated

NCR # 407627 has been initiated INITIATING CUE: The CRS has directed you to complete the necessary OMM-007 attachment(s) for the inoperability of CCW Pump B Another SRO will perform the checklist of OMM-001 -8, Control of Equipment and System Status and OPS-NGGC-1 000, Fleet Conduct of Operations.

All necessary outside notifications will be made by the Shift Manager.

2011-2 NRC JPMAdmin SROA1-2 NUREG 1021, Revision 9, Supplement 1

M Multiple Progress Energy Use ROBINSON NUCLEAR PLANT PLANT OPERATING MANUAL VOLUME 3 PART 1 OMM-007 EQUIPMENT INOPERABLE RECORD REVISION 85 OMM-007 Rev. 85 Page 1 of 88

SUMMARY

OF CHANGES PRR 00475956 OMM-007, Revision 85 STEP REVISION COMMENTS Agreement 2.41 Added reference to NGGM-IA-0003, Transmission Interface r

for Operation, Maintenance, and Engineering Activities at Nuclea Plants (NCR 471699)

NCR Step 8.2.9 Added information to refer to NGGM-lAOOO3. (PRR 00475956, 471699) (Editorial Change)

Page 2 of 88

[ OMM-007 Rev. 85

TABLE OF CONTENTS PAGE SECTION 5

1.0 PURPOSE 6

2.0 REFERENCES

8 3.0 RESPONSIBILITIES 8

4.0 PREREQUISITES 8

5.0 PRECAUTIONS AND LIMITATIONS 8

6.0 SPECIAL TOOLS AND EQUIPMENT 8

7.0 ACCEPTANCE CRITERIA 9

8.0 INS TR UC TIO NS 9 8.1 General Use 11 M/RG 1.97 8.2 Completion of EIR ITSJTRM/ODC 15 8.3 Completion of EIR Fire Protection ortant to Equipment And Other Equipment Imp 8.4 Com plet ion of EIR DS I SBO 18 Safety enta tion 22 orimetric Program Instrum 8.5 Completion of EIR Continuous Cal k (UHS) For Service Water 8.6 Completion of EIR Ultimate Heat Sin 23 Temperature Exceeding 97°F 25 8.7 Required Event Tracking 26 8.8 Loss Of Safety Function Worksheet to Components That Will Be Returned 8.9 Inoperable ITSITRMIODCMIRG 1.97 28 Service Prior to End of Shift 30 9.0 RECORDS Rev. 85 Page 3 of 88 OMM-007

TABLE OF CONTENTS (Continued)

PAGE SECTION 30 10.0 ATTACHMENTS 31 10.1 EIR ITS/TRM/ODCM/RG 1.97 33 UATION SYSTEM 10.2 EIR FIR E DE TEC TIO N AND ACT 35 10.3 EIR FIRE WATER SYSTEMS 37 AND FIRE BARRIERS 10.4 EIR GASEOUS SUPPRESSION 39 PROTECTION EQUIPMENT 10.5 EIR MISCELLANEOUS FIRE TO OTHER EQUIPMENT IMPORTANT 10.6 EIR DS I SBO EQUIPMENT AND 41 SAFETY UM EN TA TIO N .44 ETRIC PROGRAM INSTR 10.7 EIR CONTINUOUS CALORIM S) FOR SERVICE WATER 10.8 EIR ULTIMATE HEAT SINK (UH 49 TEMPERATURE EXCEEDING 97°F 53 10.9 REQUIRED EVENTTRACKING 55 10.10 MAINTENANCE RULE SYSTEMS 57 WORKSHEET 10.11 LOSS OF SAFETY FUNCTION OTHER EQUIPMENT IMPORTANT TO 10.12 DS I SBO EQUIPMENT LIST AND 61 SAFETY LE ITSITRM/ODCM/RG 1.97 10.13 FLOWCHART FOR INOPERAB RNED TO SERVICE PRIOR TO END COMPONENTS THAT WILL BE RETU 88 OF SHIFT Rev. 85 Page 4 of 88 OMM-007

1.0 PURPOSE TRM the inoperabillty of ITS components, 1.1 To provide a means of documenting ent, Ded icat ed Protection equipm components, ODCM components, Fire intenance Rule equipment, Regulatory Shutdown and SBO equipment, NRC Ma other equipment important to safety for Guide 1.97 (RG 1.97) instruments, or when the component will remain unplanned component inoperability OR 02199) inoperable past shift turnover. (CR 95-able equipment from the time of 1.2 To provide a means of tracking inoper d to rned to operable or no longer require inoperability until the equipment is retu be operable due to plant conditions ng before further action is required.

1.3 To provide a record of the time remaini ent pro vid e a mec han ism to con sist entl y control out of service time of equipm 1.4 To RG 1 .97 instruments, that is not which is important to safety, including the vide the mechanism for determining associated with an ITS LCO and to pro sato ry able and for identifying compen vulnerability while a component is inoper action. (ACR 94-1172) measures as a pre-planned course of ce Rule High Safety Significant System To provide a check for NRC Maintenan 1.5 unplanned, and provide documentation applicability, when the unavailability is that a CR was generated.

ted perable inputs to calorimetric are dele To provide a mechanism to ensure ino gra m.

1.6 sca n and ther eby pre ven ting pot entially erroneous output from the pro from in the pro vid e inst ruc tion s and a form to supplement the instruction contained 1.7 To n Determination.

TRM for performing a Safety Functio 90) nt based surveillances. (CR 98-008 1.8 To provide a method of tracking eve Rev. 85 Page 5 of 88 OMM-007

2.0 REFERENCES

Shift Relief 2.1 OMM-001-12, Minimum Equipment List and 2.2 Improved Technical Specifications (ITS) l (TRM) 2.3 PLP-100, Technical Requirements Manua 2.4 Offsite Dose Calculation Manual (ODCM) and Screening Process 2.5 CAP-NGGC-0200, Condition Identification 2.6 RAIL # 88-R0429 (Attachment 6.7) 2.7 AOP-041, Response to Fire Event 2.8 FP-001, Fire Emergency Equipment and Compensatory 2.9 FP-012, Fire Protection Systems Minimum Actions s

2.10 FP-014, Control of Fire Barrier Penetration asurement to HVH 1-4 2.11 PPP-114, Service Water Temperature Me nance CM -20 1, Saf ety Rel ated and Non -Safety Related Heat Exchanger Mainte 2.12 t was lared out of service and a Work Reques 2.13 ACR 94-00281, LT-604 was dec not promptly initiated rms Firing Dampers 2.14 ACR 92-00076, Spurious Fire Ala ely Fire Protection System Impairment in a Tim 2.15 ACR 94-01019, Failure to Report Manner e

on Identified Concerning Failure to Provid 2.16 ACR 94-1172, Potential Violati t Hydrogen Vent B Train Filter from Guidance for Removal of Post Acciden Service for Maintenance Prefix Due to Redundant Use 2.17 ACR 94-00407, Changing HS to FH ce Rule Implementation 2.18 CR 95-02199, NRC Maintenan nt to the Miscellaneous Equipment Importa 2.19 CR 95-02660, Inconsistent Use of Safety EIR Rev. 85 Page 6 of 88 OMM-007

ipment OOS Time Was Limited 2.20 CR 95-02670, WR Did Not Identify Equ Pressure Channel 2.21 CR 96-01631, CT-494 for C SIG R-OP-97-01 Weakness 2.22 CR 97-01941, NAS Assessment Risk Assessment 2.23 OMM-048, Work Coordination and itoring Violation for Missed Unavailability Mon 2.24 CR 97-02229, Maintenance Rule 14 2.25 CR 98-00890, Failure to Perform OST-0 f-Assessment 2.26 CR 98-02232, Appendix R Sel R-FP-99-01 Weakness 2.27 CR 99-00434, NAS Assessment lared out of service following RFO-18 2.28 CR 99-00505, HVE-15A not dec owable t Exchanger Analysis to Determine All 2.29 RNP-M/MECH-1 649, EDG Hea Ultimate Heat Sink Temperature erator Static and Dynamic Analysis 2.30 RNP-E-8.016, Emergency Diesel Gen n of in recommendation IC for notificatio 2.31 SOER 99-1, Loss of Grid (Credit taken g.)

d Dis patc her con cern ing equ ipm ent limitations which may be load affectin Loa Measurement 2.32 EC 47152, Ultrasonic Feedwater Flow Modification 2.33 EC 51539, SDAFW Self Cooling p A Unavailability 2.34 NCR 102997, Deep Well Pum 2.35 EC 52753, CS/SI Pump Test Line ns 2.36 EC 54786, Secondary Fighting Positio 2.37 EC 59128, Temporary Skid Diesel Diesel 2.38 SP-1 51 7, Operating the Temporary Skid OOS uired and Not Done Prior to WCCU-1A 2.39 NCR 193057 (CAPR), SFD Req de 1.97 Components 2.40 TMM-026, List of Regulatory Gui intenance, Interface Agreement for Operation, Ma 2.41 NGGM-IA-0003, Transmission Plants and Engineering Activities at Nuclear Rev. 85 Page 7 of 88 OMM-007

3.0 RESPONSIBILITIES 3.1 The SM OR CRS shall ensure:

ent is made or found inoperable.

Applicable EIRs are initiated when equipm AND ly closed out when the equipment is The EIRs are completed OR electronical equipment is no longer required returned to service (operable) or when the due to a change in plant conditions.

ns should be contacted to provide 3.2 For consistency, the Manager-Operatio m allowed time equipment may be guidance for establishing the maximu ions cific ITSJTRMIODCMIRG 1.97 limitat inoperable, for equipment without spe n during that time.

and compensatory measures to be take 4.0 PREREQUISITES N/A 5.0 PRECAUTIONS AND LIMITATIONS N/A 6.0 SPECIAL TOOLS AND EQUIPMENT N/A 7.0 ACCEPTANCE CRITERIA N/A Rev. 85 Page 8 of 88 OMM-007

REFERENCE USE 8.0 INSTRUCTIONS 8.1 General Use ed for components required by 8.1.1 Attachment 10.1 is required to be perform ic equivalent EIR, in leiu of ITS, TRM, ODCM, or RG 1.97. An electron the requirements of the Attachment 10.1, may be used provided ed under all plant conditions, attachment are met. This EIR is perform Mode applicability or plant except as noted below, without regards to ITS LCO 3.0.6 is applied condition. This is necessary to ensure that the components which are appropriately. This EIR is required since

, ODCM, or RG 1.97.

tracked by this EIR are required by ITS, TRM category, depending upon the Attachment 10.6 could also fall into this equipment being tracked. (CR 95-2660) service for an extended

1. Components which are normally out of applicable to the LCO period of time under Modes which are not ditions are met:

need not be tracked provided the below con the current plant The affected component is not required for Mode.

will assure the Procedures OR programs are in place that entering a Mode component is restored to service prior to requiring the component.

2. Examples of these types of components are:

diated fuel.

HVE-15A, only required when moving irra ng A or C.

B SI Pump, only required when replaci 5 are required to be performed 8.1.2 Attachments 10.2, 10.3, 10.4 and/or 10.

are generally referred to as Fire under all plant conditions. These EIRs d since the equipment which is Protection EIRs. These EIRs are require t NFPA requirements and to tracked by these EIRs is necessary to mee unit insurance carrier, Nuclear meet commitments made to the nuclear 2660)

Electric Insurance Limited (NEIL). (CR 95-Rev. 85 Page 9 of 88 OMM-007

formed when a component/system 8.1.3 Attachment 10.6 is required to be per inoperable OR when it has been identified on Attachment 10.12 is found ument and track the determined necessary or desirable to doc

s. This EIR is required in inoperability of other components/system d in the DS/SBO Equipment MODE 1, 2, 3 or 4 if the equipment is liste the equipment tracked is List of Attachment 10.12 since much of fire or a Station Blackout event.

credited for coping with an Appendix R icated Shutdown I SBO and This EIR is generally referred to as the Ded EIR. (CR 95-2660)

Other Equipment Important to Safety performed when a component that 8.1.4 Attachment 10.7 is required to be orimetric Program becomes supplies an input into the Continuous Cal rred to as the Continuous inoperable. This EIR is generally refe (CR 96-01631)

Calorimetric Program Instrumentation EIR.

performed when the Service Water 8.1.5 Attachment 10.8 is required to be ITS LCO 3.7.8 REQUIRED temperature exceeds 97°F and entry into or 4. This EIR identifies the ACTIONS is necessary in Modes 1, 2, 3, entation and equipment necessary checks to insure plant docum atures up to 99°F.

supports elevated Service Water temper er track event based surveillances and oth 8.1.6 Attachment 10.9 is required to may be used to trac k similar events. An electronic equivalent surveillances. (CR 98-00890)

EIRs to determine whether the 8.1.7 Attachment 10.10 is referenced from all nance Rule High Safety equipment inoperability affects a Mainte required functions are checked Significant System. If so, the systems Attachment 10.10 also contains a on the Maintenance Rule Database.

ability monitoring for the list of all systems which require unavail maintenance rule.

Function Determination (SFD) 8.1.8 Attachment 10.11 is used when a Safety is performed. [CAPR 193057]

Rev. 85 Page 10 of 88 OMM-007

where the component will 8.1.9 During the performance of planned activities shift, an EIR is not required.

be returned to service prior to the end of the d by the EIR must still be However, any compensatory actions require watch or deleting ERFIS performed (such as posting a continuous fire ent should be logged for points from scan). In addition, the compon Flowchart for tracking purposes. Use Attachment 10.13, of Service Less Than One ITS/TRM/ODCM/RG 1.97 Components Out CM/RG 1.97 components Shift, when it is anticipated that ITS/TRM/OD service prior to the end rned to that have become inoperable will be retu of shift. [CAPR 193057]

ivalent can be used for a variety of 8.1.10 The EIR form OR electronic equ documentation that do not inoperable equipment. Those spaces for ked N/A.

apply to the current use should be mar maintained in the Control Room EIR 8.1.11 The outstanding EIR(s) shall be wed each shift as long as the Book OR tracked electronically AND revie equipment is inoperable.

time is approaching the time allowed 8.1.12 When equipment out of service ment should be notified to identified on the EIR, Operations manage Work Control process.

escalate the priority of the task using the (CR 95-02670) ry actions, evaluate the need to 8.1.13 Prior to implementing compensato 010 to assess to impact of the perform a screen under REG-NGGC-0 cedures described in the compensatory action on the facility or pro UFSAR.

8.2 Completion of EIR ITSITRM/ODCM/RG 1.97 (UHS) For Service Water NOTE: Completion of EIR Ultimate Heat Sink d versus this section if entering ITS Temperature Exceeding 97°F will be use due to Service Water temperature LCO 3.7.8 (UHS) REQUIRED ACTIONS exceeding 97°F.

8.2.1 Perform the Revision Verification.

is inoperable in Section A.

8.2.2 Enter the name of the equipment which erability. This may include 8.2.3 Record the reason for the equipment inop ent, and/or work to be MOD number, problems with the equipm performed.

(if applicable) AND record the 8.2.4 Verify a Work Request has been initiated WR number (ACR 94-00281).

Rev. 85 Page 1 1 of 88 OMM-007

nt is part of a 8.2.5 IF the unavailability is unplanned, AND the compone w OMM-048 AND the system listed on Attachment 10.10, THEN revie Criteria Basis section of Maintenance Rule Scoping and Performance if the listed function(s) of the Maintenance Rule Database to determine the system is/are affected.

CR stating a potential IF a system function is affected, THEN initiate a rred lAW OMM-048, and Safety Significant Functional Failure has occu record the CR # in Section D.

8.2.6 Complete Section E as follows:

pment was declared Item 1 Enter the TIME AND DATE that the equi inoperable.

ion and enter Item 2 Circle the applicable document abbreviat Be specific. For applicable LCD, TRMS or Specification number.

where applicable.

example, provide table number and item number Examples: LCD 3.3.1, Table 3.3.1-1 Item 7.a TRMS 3.10, Table 3.10-1 Item 3 Specification 2.6.3, Table 2.6-1 Item 4.c to satisfy the Item 3 Enter any applicable actions required completion time.

document identified in Item 2 and any required ce Examples: Place channel in trip within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months OR redu THERMAL POWER to <P-7 within 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s.

s Restore required channel to OPERABLE statu within 7 days OR submit Special Report to NRC outlining.., within 14 days days Return instrument to operable status within 30 ual and if unsuccessful explain reason in next Ann Radioactive Effluent Release Report Rev. 85 Page 12 of 88 OMM-007

8.2.6 (Continued) ipment is allowed to be Item 4 Enter the maximum time the equ hrs/days as they apply to inoperable in the applicable blank. Circle the Special Report.

4 is required in the Item 5 Enter the Time AND Date that item applicable blank.

ples lack a grace period.

NOTE: ODCM required initial compensatory sam es or activities and required Item 6 Enter any applicable surveillanc lt of the component frequencies which are required as a resu inoperability.

requires SR Examples: ITS LCO 3.2.4 REQUIRED ACTION A.3 3.2.1.1 and 3.2.2.1 once per7 days.

requires the ITS LCO 3.6.3 REQUIRED ACTION A.2 ied isol ated once affected penetration flow path verif CV.

per 31 days for isolation devices outside SATORY TRM TRMS 3.11 REQUIRED COMPEN lyzi ng grab MEASURE requires obtaining and ana n

samples once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter, whe degassing is not in progress.

tem component, THEN perform 8.2.7 IF the component is an ITS Support Sys ensure Safety Function Attachment 10.11, which is provided to

y. The TRM contains in-depth Determinations are performed consistentl n Determinations.

guidance for performing Safety Functio

[CAPR 193057]

tem Component, THEN 8.2.8 IF the component is an ITS Supported Sys rksheets (Attachment 10.11) for review open Loss of Safety Function Wo review. [CAPR 193057]

impact AND log in AUTO log to document Dispatcher has been 8.2.9 Initial the blank in Section H when the Load ity could force plant shutdown or notified when the component inoperabil 03.[SOER 99-1, Rec. 1C]

load reduction. Refer to NGGM-IA-00 n Planning and Scheduling has been 8.2.10 Initial the blank in Section 1 whe actions have been entered and notified when ITS/TRMJODCM/RG 1.97 plant shutdown is anticipated.

Rev. 85 Page 13 of 88 OMM-007

Monitor, Flowrate Monitor or 8.2.11 IF the EIR is completed due to a Radiation enter the E&C Technicians Tank Level Monitor inoperability, THEN blanks in Section J.

name, time and date of notification in the found by clicking on Start, Programs, NOTE: Maintenance Rule data can be ebook. When the database opens Engineering, RNP, and RNP System Not of available systems to the list of move the desired system(s) from the list Notebook links click on M. R.

selected systems. From the list of System Performance Summary.

System Specific Reports, then click on t

monitored for unavailability (Attachmen 8.2.12 IF a Maintenance Rule System rd the Allowed Unavailability 10.10, page 2) is affected, THEN reco hours, and record the remaining hours, subtract the actual unavailability 102997) unavailability hours in Section K. (NCR ed and remaining unavailability hours are 8.2.13 IF the unavailability is unplann nager and record the name, less the 72, THEN notify the RES Duty Ma 997) date, and time in Section K. (NCR 102 iew the EIR AND sign AND date following 8.2.14 The SM OR the CRS shall rev completion in Section L.

d d for documenting failed testing or change 8.2.15 The comments section is use equipment status.

Control Room EIR Book.

8.2.16 Place the completed EIR in the d to service OR the equipment is no 8.2.17 When the equipment is returne t conditions, Section N is longer required due to a change in plan completed as follows:

operable, THEN enter the Item 1 IF the equipment is declared declared operable.

TIME AND DATE that the equipment is a Radiation Monitor, Flowrate Item 2 IF the EIR is completed due to ity, THEN enter the E&C Monitor or Tank Level Monitor inoperabil rned to service.

Technicians name, time AND date retu uired, THEN enter the Item 3 IF the equipment is no longer req equipment is no longer TIME, DATE, AND REASON why the required (such as, MODE 5 entered).

date the EIR.

Item 4 The SM OR CRS shall sign AND Rev. 85 Page 14 of 88 OMM-007

8.3 Completion of EIR Fire Protection 8.3.1 Perform the Revision Verification.

ent in Section A.

8.3.2 Enter the name of the inoperable equipm AND DATE the 8.3.3 Complete Section B by entering the TIME applicable inoperable compensatory actions were initiated for the equipment.

8.3.4 Complete Section C as follows:

ponent is part of a IF the unavailability is unplanned, AND the com review OMM-048 AND the system listed on Attachment 10.10, THEN e Criteria Basis section of Maintenance Rule Scoping and Performanc rmine if the systems listed the Maintenance Rule Database, to dete function(s) is affected.

te a CR stating a potential IF a system function is affected, THEN initia occurred lAW OMM-048, and Safety Significant Functional Failure has record the CR #.

intenance Rule or Attachment 10.5 is not applicable to the Ma OMM-048 evaluation.

8.3.5 Complete Section D as follows:

equipment was declared Item 1 Enter the TIME AND DATE the inoperable.

perable. This may include Item 2 Explain why the equipment is ino ent, and/or work to be MOD number, problems with the equipm performed.

ipment is required to be Item 3 Enter the TIME AND DATE the equ tion of the EIR for the returned to service. Refer to applicable por allowed equipment inoperable duration.

Equipment out of service for greater NOTE: NCRs are generated for Fire Protection ure proper tracking.

than the time allowed by FP-012 to ens e allowed by FP

a. WHEN an NCR is initiated due to the tim the following:

012 being exceeded, THEN CONSIDER ject that is

1. The NCR should be assigned to the pro allowed creating the impairment for greater than the time.

Rev. 85 Page 15 of 88 OMM-007

8.3.5 (Continued)

2. All NCRs should be given a Priority 3 for tracking AND trending purposes only.

3. Impairments exceeding the allowed time due to a project or other non-repair activity should not be listed as equipment related.

4. When an NCR is written, the project or reason for exceeding the allowed time needs to be included to allow assignment to the appropriate group OR individual.

5. NCR should be written as no further review required with an explanation that the NCR is written for tracking AND trending purposes.

Item 4 Enter as follows:

a. Attachments 10.2 and 10.3 IF the equipment is expected to be inoperable more than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , OR WHEN the equipment has been inoperable for 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , THEN within one working day, Operations shall notify the RESS Fire Protection Engineer personnel AND document this notification on the EIR.8.3.5 (Continued)

b. Attachment 10.4 For inoperable damper(s) verify that appropriate compensatory actions have been determined AND initiated lAW FP-014 and complete Item D.4 of Attachment 10.4. (ACR 92-00076).

),

NOTE: The nuclear unit insurance carrier, Nuclear Electric Insurance Limited (NEIL requires notification when impairments to an active Fire Protection System (such as, Fire Pumps, Fire Hydrants/Hose Stations, Sprinkler/Deluge Systems, or Detection! Suppression Systems) exceeds OR is expected to tion exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . Operations personnel shall notify the RESS Fire Protec Engineer of any such impairment.

Item 5 (Item 6 on Attachment 10.4, Item 4 on Attachment 10.5)

Verify a Work Request has been initiated (if applicable) AND record the WR number. (ACR 94-00281)

Rev. 85 Page 16 of 88 OMM-007

8.3.5 (Continued)

, Programs, NOTE: Maintenance Rule data can be found by clicking on Start the database opens Engineering, RNP, and RNP System Notebook. When systems to the list of move the desired system(s) from the list of available links click on M. R.

selected systems. From the list of System Notebook Summary.

System Specific Reports, then click on Performance em monitored Item 6 Attachment 10.3 IF a Maintenance Rule Syst THEN for unavailability (Attachment 10.10, page 2) is affected, s, subt ract the actua l record the Allowed Unavailability hour unav ailab ility hours.

unavailability hours, and record the remaining (NCR 102997) anned and Item 6 Attachment 10.3 IF the unavailability is unpl N notify the remaining unavailability hours are less the 72, THE and time .

RES Duty Manager and record the name, date, (NCR 102997) chment 10.5)

Item 7 (Item 7 on Attachment 10.4, Item 5 on Atta The SM OR CRS shall sign AND date the EIR.

chment 10.5)

Item 8 (Item 8 on Attachment 10.4, Item 6 on Atta nt status can General comments, failed testing or changed equipme be added to the Comments portion.

k.

8.3.6 Place the completed EIR in the Control Room EIR Boo plete Section E 8.3.7 WHEN the equipment is returned to service, THEN com as follows:

ned to service.

Enter the TIME AND DATE that the equipment is retur The SM OR CRS shall sign AND date the EIR Rev. 85 Page 17 of 88 OMM-007

ired if the affected component NOTE: The EIR for DS / SBO equipment is NOT requ therefore covered under another is required by Technical Specifications and ing than the allowed out of EIR and the ITS required actions are more limit service time for the DS/SBO.

Important to 8.4 Completion of EIR DS / SBO Equipment And Other Equipment Safety 8.4.1 Peilorm the Revision Verification.

able due to blocking of the 8.4.2 IF a safe shutdown pathway is made inoper allow access/egress for safe pathway OR a security door or gate will not shutdown events, THEN initiate an EIR.

weather enclosure may be 8.4.3 A safe shutdown pathway blocked by a cold by the Appendix R declared operable if the enclosure is approved the construction/installation Engineer (the pathway is inoperable during of the enclosure). NCR 248962 le as long as their TS surveillances NOTE: Items powered from PP-50 remain operab still operable as long as they are are met. Specifically, these components are ry or DS UPS is inoperable.

energized and operating, even if the DS batte nt Inoperable from the list 8.4.4 In Section C, enter the name of the Equipme pment List and Other provided in Attachment 10.12, DS / SBO Equi ther the equipment is Equipment Important to Safety. Indicate whe Shutdown/SBO.

Important to Safety OR needed for Dedicated Rev. 85 Page 18 of 88 OMM-007

8.4.5 Complete Section D as follows:

Security IF D Deepwell Pump becomes unavailable, THEN notify atory Acti ons.

immediately to implement Security Compens purpose List any component that can be used to serve the same T

(whether from the same location OR not) in the REDUNDAN EQUIPMENT AVAILABLE column, as appl icabl e.

which are used to make NOTE: The instruments listed in Attachment 10.12 are those

)

major decisions in the EOP5/AOPs/DSPs. (CR 95-02660 ager should be For consistency, the Manager-Operations or On-call Man imum allowable time contacted to provide guidance for establishing the max ures to be taken equipment may be inoperable and compensatory meas during that time.

Assess AND identify the VULNERABILITIES DUE TO against affected UNAVAILABILITY of the component when evaluated procedures listed in Attachment 10.12.

ent 10.12, but is IF the inoperable component is not listed in Attachm vulnerability that to be tracked lAW this procedure, THEN identify the s that may be caused that determination. Examples of vulnerabilitie itori ng of parameters, listed are: manual actions required, local mon no annunciator available, no indication available, etc.

necessary to IF any compensatory measures are determined to be uctio nal Aid aid in mitigating the vulnerability (such as an Instr alter nate attached to the inoperable component identifying shift equipment, shift turnover discussion documented on the state them turnover sheets, ERFIS points to be trended, etc.), THEN ESS ARY colu mn.

in the COMPENSATORY MEASURES NEC Rev. 85 Page 19 of 88 OMM-007

8.4.6 The SM/Manager Operations shall sign and date Section E stating that the compensatory actions are adequate.

8.4.7 Complete Section F as follows:

IF the unavailability is unplanned, AND the component is part of a system listed on Attachment 10.10, THEN review OMM-048 AND the Maintenance Rule Scoping and Performance Criteria Basis section of the Maintenance Rule Database, to determine if the systems listed function(s) is affected.

IF a system function is affected, THEN initiate a CR stating a potential Safety Significant Functional Failure has occurred lAW OMM-048, and record the CR #.

8.4.8 Complete Section G as follows:

Item I Enter the TIME AND DATE that the equipment was declared inoperable.

Item 2 Document the reason why the equipment is inoperable.

This may include MOD number, problems with the equipment, and/or work to be performed.

Item 3 Verify a Work Request has been initiated (if applicable) AND record the WR number (ACR 94-00281).

Item 4 Document the time the component is allowed to be inoperable.

Item 5 Document individuals notified.

Item 6 IF this EIR is for the Dedicated Shutdown radios, THEN check at least nine Dedicated Shutdown radios are operable.

Item 7 IF the equipment is NOT inoperable due to scheduled work, THEN the SM/CRS shall verify that the WR contains the appropriate priority, time allowed out of service, and the statement that the equipment is important to safety and should not be downgraded.

OMM-007 Rev. 85 Page 20 of 88

8.4.8 (Continued)

NOTE: Maintenance Rule data can be found by clicking on Start, Programs, Engineering, RNP, and RNP System Notebook. When the database opens move the desired system(s) from the list of available systems to the list of selected systems. From the list of System Notebook links click on M. R.

System Specific Reports, then click on Performance Summary.

Item 8 IF a Maintenance Rule System monitored for unavailability (Attachment 10.10, page 2) is affected, THEN record the Allowed Unavailability hours, subtract the actual unavailability hours, and record the remaining unavailability hours. (NCR 102997)

Item 8 IF the unavailability is unplanned and remaining unavailability hours are less the 72, THEN notify the RES Duty Manager and record the name, date, and time. (NCR 102997)

Item 9 The SM OR CRS shall sign AND date the EIR.

Item 10 Self explanatory.

8.4.9 Place the completed EIR in the Control Room EIR Book.

8.4.10 IF the plant is in MODE 1,2, 3 or4, the equipment is listed on Attachment 10.12 DS/SBO Equipment List, AND the equipment is not restored to operable status within 14 days, THEN complete Section H by initiating a Condition Report AND recording in the space provided.

8.4.11 WHEN the equipment is returned to service OR the equipment is no longer required due to a change in plant conditions, THEN Section I shall be completed as follows:

Item I Enter the TIME AND DATE that the equipment is declared operable.

OR Item 2 Enter the TIME, DATE, AND REASON why the equipment is no longer required (such as, MODE 5 entered).

Item 3 The SM OR CRS shall sign AND date the EIR.

OMM-007 Rev. 85 Page 21 of 88

entation 8.5 Completion of EIR Continuous Calorimetric Program Instrum (CR 96-01631) 8.5.1 Perform the Revision Verification.

PERABLE in Section A.

8.5.2 Enter the name of the EQUIPMENT INO 8.5.3 Complete Section B as follows:

ete Inputs for the ERFIS Using the Turn on Code CALO select Del ipment to remove the Point(s) associated with the inoperable equ gram calculations OR point(s) from Continuous Calorimetric Pro ciated with the inoperable delete from scan the ERFIS point(s) asso equipment.

on is performed.

Enter the DATE AND TIME the above acti rement (FWUFM) system is IF the Feedwater Ultrasonic Flow Measu NOT available, THEN apply TRMS 3.25.

8.5.4 Complete Section C as follows:

component is part of a IF the unavailability is unplanned, AND the review OMM-048 AND the system listed on Attachment 10.10, THEN e Criteria Basis section of Maintenance Rule Scoping and Performanc rmine if the listed function(s) the Maintenance Rule Database to dete of the system is/are affected.

te a CR stating a IF a system function is affected, THEN initia Failu re has occurred lAW potential Safety Significant Functional OMM-048, and record the CR #.

8.5.5 Complete Section D as follows:

the equipment was declared Item 1 Enter the TIME AND DATE that ERFIS point was removed inoperable, the COP was disabled or the from scan.

equipment is inoperable.

Item 2 Document the reason why the s with the equipment, and/or This may include MOD number, problem work to be performed.

date the EIR.

Item 3 The SM OR CRS shall sign AND Item 4 Self-explanatory.

Rev. 85 Page 22 of 88 OMM-007

EIR Book.

8.5.6 Place the completed EIR in the Control Room the equipment is no 8.5.7 When the equipment is returned to service OR itions, Section E shall be longer required due to a change in plant cond completed as follows:

ipment was declared Item 1 Enter the TIME AND DATE that the equ now be restored to scan operable. The associated ERFIS point may tric Program.

or the input restored to the Continuous Calorime OR why the equipment is Item 2 Enter the TIME, DATE, AND REASON E 1).

no longer required (such as unit no longer in MOD the EIR.

Item 3 The SM OR CRS shall sign AND date Temperature 8.6 Completion of EIR Ultimate Heat Sink (UHS) For Service Water Exceeding 97°F 8.6.1 Perform the Revision Verification.

entry into ITS LCO 3.7.8 8.6.2 Record the time and date in Section A that REQUIRED ACTIONS occurred.

8.6.3 For Section B, perform the following:

or equal to 99°F

1. Verify Service Water temperature is less than PPP -1 14.

once per hour and log temperature per

2. Within ONE HOUR:

ument revisions are Using PASSPORT verify the affected doc available OR the current with the memo. IF PASSPORT is not agree with the revision and pending change status does not all RESS manager Engineering memo, THEN contact the On-C s have been to assure no revision OR pending change ld invalidate the approved against the documents which wou CRS will sign when Engineering memo AND the SM OR the the initial check is completed.

Rev. 85 Page 23 of 88 OMM-007

8.6.3.2 (Continued) ities since Review plant logs, EIRs, and scheduled work activ any the Engineering memo was initiated to assure maintenance that was performed on the listed heat the exchangers DID NOT involve tube plugging and that OR the CRS will components are OPERABLE AND the SM sign when the initial check is completed.

ks in Auto Record completion of reviews and equipment chec Log by ITS LCO 3.7.8 8.6.4 Place the unit in the appropriate Mode as required are not met.

REQUIRED ACTIONS if the above requirements atcher has been 8.6.5 Initial the blank in Section C when the Load Disp could force plant notified of the REQUIRED ACTION entry which shutdown or load reduction.

Scheduling has been 8.6.6 Initial the blank in Section D when Planning and notified plant shutdown is anticipated.

as follows:

8.6.7 Once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , Section E is completed nt with the memo Verify the affected document revisions are curre k is completed.

AND the SM OR the CRS will sign when the chec ities for the Review plant logs, EIRs, and scheduled work activ performed on the previous 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to assure no maintenance was ILITY AND that the listed heat exchangers that would affect OPERAB CRS will sign components are OPERABLE AND the SM OR the when the check is completed.

Record completion of checks in Auto Log.

Rev. 85 Page 24 of 88 OMM-007

exited OR 8.6.8 When the ITS LCO 3.7.8 REQUIRED ACTIONS have been itions, chan ge in plan t cond the ITS LCO is no longer required due to a Section F is completed as follows:

Item 1 Enter the TIME AND DATE the LCO is exited.

OR LCO is no Item 2 Enter the TIME, DATE, AND REASON why the longer required (such as, MODE 5 entered).

8.6.9 Item 3 The SM OR CRS shall sign AND date the EIR.

8.7 Required Event Tracking (CR 98-00890) period and is being NOTE: For short period events requiring less than an eight hour tracking an tracked by auto log or other reliable means including E&RC t is not requ ired.

ODCM item, a Required Event Tracking shee 8.7.1 Record the affected component in the space provided rm the 8.7.2 Record the event that initiated the requirement to perfo surveillance or other event.

itions for 8.7.3 Describe the surveillance or event to be tracked, the cond termination and any references.

Example: Completion of OST-014 lAW ITS SR 3.0.3.

t is due.

8.7.4 Record the first time and date the surveillance or even occu rrenc es.

A table is provided for documentation of multiple valve closed Example: Administratively verify Containment Isolation every 31 days.

8.7.5 The SM OR CRS shall sign and date the form.

8.7.6 Place the completed form in the Control Room EIR Book.

required or has 8.7.7 When the required surveillance or event is no longer follow s:

been performed, then complete Section E as Document the date and time completed.

The SM OR CRS shall sign and date the form.

Rev. 85 Page 25 of 88 OMM-007

8.8 Loss of Safety Function Worksheet [CAPR 193057]

NOTE: These instructions do not supersede any instructions contained in the TRM regarding how to perform a Safety Function Determination (SFD). These instructions supplement the TRM instructions and provide an aid in completing the Loss of Safety Function (LOSF) Worksheet.

This determination should be performed by a licensed Senior Reactor Operator and reviewed any time additional inoperabilities occur OR an ITS Supported Feature is declared inoperable.

8.8.1 Perform the Revision Verification.

8.8.2 Complete plant conditions table.

8.8.3 Record the ITS Support Feature which is inoperable by ITS LCO number and describe the inoperability.

8.8.4 Determine if the ITS Support Feature inoperability causes an ITS Supported Feature to not meet its LCO AND record as applicable.

8.8.5 IF no ITS Supported Feature is inoperable due to the ITS Support Feature being inoperable, THEN perform the following:

1. N/A the remaining steps and sign Completed By.

2. Forward the attachment to the SM for review.

3. IF the Support Feature will NOT be returned to service prior to end of shift, THEN attach the LOSF Worksheet to the EIR for the ITS Support Feature.

4. IF the Support Feature will be returned to service prior to end of shift, THEN file LOSF Worksheet in EIR notebook.

8.8.6 Determine if ITS Support Features LCO requires CASCADING to ITS Supported Feature(s) REQUIRED ACTION and record as applicable.

1. IF ITS Support Features LCO requires CASCADING to ITS Supported Feature(s) REQUIRED ACTION, THEN the SFD is complete.

2. N/A the remaining steps and sign Completed By.

3. Forward the attachment to the SM for review. Attach the LOSF Worksheet to the EIR for the ITS Support Feature.

OMM-007 Rev. 85 Page 26 of 88

8.8.7 Determine if any other ITS Support LCOs are not met, and record the impact of the inoperabilities on all applicable ITS Supported Features.

8.8.8 Determine if any redundant ITS Supported Features are inoperable.

1. IF no redundant ITS Supported Features are inoperable, THEN the SFD is complete.

2. N/A the remaining steps and sign Completed By.

3. Forward the attachment to the SM for review. Attach the LOSF Worksheet to the ITS Supported Features EIR.

8.8.9 IF a redundant ITS Supported Feature is inoperable, THEN determine if a Loss of Safety Function (LOSF) exists for the ITS Supported Feature.

8.8.10 IF there is no LOSF, THEN perform the following:

1. Calculate and record the maximum completion time to restore the ITS Support Feature AND associated ITS Supported Feature(s) to operable status.

2. N/A the remaining steps and sign Completed By.

3. Forward the attachment to the SM for review. Attach the LOSF Worksheet to the ITS Supported Features EIR.

8.8.11 IF there is a LOSF, THEN perform the following:

1. Calculate and record the maximum completion time to restore the ITS Support Feature and associated ITS Supported Feature(s) to operable status.

2. Enter the applicable ITS LCO for the ITS Supported Feature OR ITS LCO 3.0.3 as applicable.

3. Attach the LOSE Worksheet to the ITS Supported Features EIR.

8.8.12 The individual who completed the worksheet shall sign and date the worksheet.

8.8.13 The SM shall sign and date the worksheet.

OMM-007 Rev. 85 Page 27 of 88

ents That Will Be Returned to 8.9 Inoperable ITS/TRM/ODCM/RG 1.97 Compon Service Prior to End of Shift [CAPR 193057]

on for the equipment 8.9.1 Enter the name of the equipment AND the reas inoperability in AUTO log.

applicable) AND enter the 8.9.2 Verify a Work Request has been initiated (if WR number in AUTO log.

ponent is part of a 8.9.3 IF the unavailability is unplanned, AND the com w OMM-048 AND the system listed on Attachment 10.10, THEN revie e Criteria Basis section of Maintenance Rule Scoping and Performanc ne if the listed function(s) of the Maintenance Rule Database to determi the system is/are affected.

an NCR stating a potential 8.9.4 IF a system function is affected, THEN initiate rred JAW OMM-048, and Safety Significant Functional Failure has occu enter the NCR # in AUTO log.

number in AUTO log. Be 8.9.5 Enter applicable LCO, TRMS or Specification and item number where specific. For example, provide table number applicable.

Examples: LCO 3.3.1, Table 3.3.1-1 Item 7.a TRMS 3.10, Table 3.10-1 Item 3 Specification 2.6.3, Table 2.6-1 Item 4.c allowed to be inoperable.

8.9.6 Determine the maximum time the equipment is and required frequencies 8.9.7 Determine applicable surveillances or activities ent inoperability.

which are required as a result of the compon IF the component is an ITS Support System component, THEN perform 8.9.8 Worksheet AND file Attachment 10.11, Loss of Safety Function worksheet in EIR notebook.

Component, THEN 8.9.9 IF the component is an ITS Supported System eets for impact AND enter review open Loss of Safety Function Worksh in AUTO log to document review.

Rev. 85 Page 28 of 88 OMM-007

itor, Flowrate Monitor or 8.9.10 IF the inoperable component is a Radiation Mon Tank Level Monitor, THEN notify E&C.

t shutdown or load 8.9.11 IF the component inoperability could force a plan reduction, THEN notify the Load Dispatche r. [SOER 99-1, Rec. 1C]

entered AND a plant 8.9.12 IF ITS/TRM/ODCM/RG 1.97 actions have been duling.

shutdown is anticipated, THEN notify Planning and Sche the equipment is no 8.9.13 WHEN the equipment is returned to service OR N perform the longer required due to a change in plant conditions, THE following:

following:

IF the equipment is declared operable, THEN perform the o Enter in AUTO log.

o IF the equipment is a Radiation Monitor, Flow rate Monitor or Tank Level Monitor, THEN notify E&C.

reason in IF the equipment is no longer required, THEN enter the AUTO log (such as, MODE 5 entered).

Rev. 85 Page 29 of 88 OMM-007

9.0 RECORDS ksheets shall be routed to 9.1 Completed EIRs AND Loss of Safety Function Wor Plant Records.

10.0 ATTACHMENTS 10.1 EIR ITS/TRM/ODCM/RG 1.97 10.2 EIR Fire Detection and Actuation System 10.3 EIR Fire Water Systems 10.4 EIR Gaseous Suppression and Fire Barriers 10.5 EIR Miscellaneous Fire Protection Equipment rtant to Safety 10.6 EIR DS I SBO Equipment And Other Equipment Impo 10.7 EIR Continuous Calorimetric Program Instrumentation perature Exceeding 97°F 10.8 EIR Ultimate Heat Sink (UHS) For Service Water Tem 10.9 Required Event Tracking 10.10 Maintenance Rule Systems 10.11 Loss of Safety Function Worksheet pment Important to Safety 10.12 DS / SBO Equipment List And Other Equi RG 1.97 Components That Will Be 10.13 Flowchart for Inoperable ITSJTRM/ODCM/

Returned to Service Prior to End of Shift Rev. 85 Page 30 of 88 OMM-007

ATTACHMENT 10.1 Page 1 of 2 EIR - ITSITRMIODCMIRG 1.97 CONTINUOUS USE revision available.

This revision has been verified to be the latest Date INIT le:

erab nt Inop pme Equi A.

B. Reason for Equipment Inoperability:

WR __

C. WR initiated: (ACR 94-00281)

Safety Significant Maintenance Rule System D. IF an unplanned unavailability AND a High N initiate CR stating a potential safety FUNCTION is affected by the equipment, THE CR #

significant functional failure has occurred.

E. Operating Limitations:

Date

1. Equipment declared inoperable: Time ber

2. ITS/TRM/ODCM/RG I .97Other reference num (Circle one)

3. Other actions and associated completion time:___

re:

4. Maximum time equipment allowed inoperable befo Hrs E 3 Hrs MOD E 4_ Hrs MODE 5 MODE 2_ Hrs MOD Special Report hrs/days

5. Time AND Date Action Required:

Time: Date:

MODE 2 Time: Date:

MODE 3 Date:

Time:

MODE 4 Date:

Time:

MODE 5 Time: Date:

Special Report rmed as a result of the inoperability of this

6. Record any surveillance required to be perfo les lack a grace period.)

component. (ODCM initial compensatory samp Rev. 85 Page 31 of 88 OMM-007

_____Ho____

urs____

(SM ATTACHMENT 10.1 Page 2 of 2 EIR ITSITRM/ODCMIRG 1.97 perform Attachment 10.11.

F. IF this is an ITS Support System Component, THEN

[CAPR 193057]

review open Loss of Safety Function G. IF this is an ITS Supported System Component, THEN Worksheets (Attachment 10.11) for impact.

which could force plant shutdown/load H. Load Dispatcher notified of REQUIRED ACTION reduction. Initials) [SOER 99-1, Rec. 1C]

ed Outage Schedule if I. Planning and Scheduling notified to develop Forc t shutdown anticipated.

ITS/TRM/ODCM/RG 1.97 actions are entered AND plan Initials)

Monitor or Tank Level Monitor, THEN notify J. IF this EIR is for a Radiation Monitor, Flowrate E&C of equipment inoperability:

Time Date E&C Shift Technician (Print name) ted, THEN record Allowed Unavailability K. iF a Maintenance Rule System Function is affec ility Hours Remaining.

Hours, Actual Unavailability Hours, and Unavailab Allowed -

Hours Actual Hours Remaining

, THEN notify the RES Duty Manager.

IF unplanned and less than 72 Hours remaining Date Time Name L. Completed By: Date SM/CRS M. Comments:

N. Restoration

1. Equipment operable: Time Date itor or Tank Level

2. IF this EIR is for a Radiation Monitor, Flowrate Mon nt retur n to servi ce:

Monitor, THEN notify E&C of equipme Time Date E&C Shift Technician (Print Name) itions:

3. Equipment no longer required due to plant cond Time Date Reason:

4. Completed By: Date SM/CRS Rev. 85 Page 32 of 88 OMM-007

ATTACHMENT 10.2 Page 1 of 2 ATION SYSTEM EIR - FIRE DETECTION AND ACTU CONTINUOUS USE n available.

This revision has been verified to be the latest revisio Date INIT A. Equipment Inoperable:

Actions B. Equipment to be Inoperable I Compensatory COMPENSATORY ACTION COMPENSATORY ACTION INITIATED COMPONENT/ZONE TIME DATE 24, 25A, 2581, 25C 1 ,

1 Initiate inspections once per shift 2

26 and 1,2,3,4, 5,7,8, 11, 13, Within one hour, begin hourly 15, 16, 17, 21, 22, 23, inspections.

27, and 28 gI 10, 121, 19, 201 Within one hour, post continuous Fire (Zones 1 and 2 if EDG Watch with backup 3 suppression operating)

Transceivers Within one hour, begin continuous monitoring of the applicable FDAP.

FDAP & Loss of Follow the compensatory action for the Detection Zone applicable system.

FAC Within one hour, begin continuous monitoring of FDAPs Al, A2, BI, & B2.

Locked in Trouble Within one hour, perform an hourly Alarm on FDAP review of applicable panel(s) for or Transceiver additional alarms received.

NOTES:

25C trains A and B and Zone 20 train B:

1 The following applies for Zones 9, 12, 24, 25A, 25B, AND will not reset, THEN it has failed safe.

a. IF a detector has actuated in the ALARM position inhibited, THEN the suppression system AND

b. IF the opposite detector train is operable AND not inspection OR fire watch NOT required.

fire detection system is considered operable. Hourly

c. FP-012 should be reviewed.

in containment, THEN no inspection can be made.

2. IF, during SIT OR ILRT, fire alarms are received in containment.

AOP-041 shall be referenced for response to alarms suppression provided.

3. IF necessary, add additional sheets describing backup Rev. 85 Page 33 of 88 OMM-007

ATTACHMENT 10.2 Page 2 of 2 ATION SYSTEM EIR FIRE DETECTION AND ACTU Significant Maintenance Rule System FUNCTION is C. IF an unplanned unavailability AND a High Safety potential safety significant functional failure affected by the equipment, THEN initiate a CR stating a has occurred. CR #

D. Operating Limitations Equipment declared inoperable. Time Date 1.

2. Reason for Equipment Inoperability:

d out of service time is NOTE: FP-012 states that an NCR shall be initiated if the allowe exceeded.

ent required to be returned to service by:

3. Time equipment allowed inoperable is 14 days. Equipm Time:

Date:

(Fire Pump, Fire Hydrant/Fire Hose,

4. IF an impairment to an active Fire Protection System

, etc.) exceeds OR is expected to Sprinkler/Deluge System, Detection/Suppression System Engine er OR Designee shall be notified within exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , THEN the RESS Fire Protection one working day (ACR 94-01019):

Time: Date:

Person Contacted WR initiated: (ACR 94-0028 1) WR #

5.

6. Completed By: Date SM/CRS

7. Comments:

E. Restoration

1. Equipment Operable: Time: Date:

2. Completed By: Date SM/CRS Rev. 85 Page 34 of 88 OMM-007

ATTACHMENT 10.3 Page 1 of 2 EIR FIRE WATER SYSTEMS CONTINUOUS USE available.

This revision has been verified to be the latest revision Date INIT able:

Inoper ent Equipm A.

B. Equipment to be Inoperable I Compensatory Actions COMPENSATORY ACTION COMPENSATORY ACTION INOPERABLE EQUIPMENT INITIATED TIME DATE RESTORE OPERABILITY WITHIN 7 DAYS Fire Water Pumps and Flowpath for Unit 2:

a. Engine OR Motor Driven Fire N/A N/A Pump None

b. Firewater Loop Flowpath with None (See Items 8.2 through B.6 below, if N/A N/A section of loop isolated by applicable) closing sectional isolation valve(s)

c. Firewater Loop Flowpath section isolation valve closed OR None N/A N/A inoperable.

d. Supply Header section isolation NOTE: Compensatory actions shown below for OR system isolation valve for B.2 through B.6 systems. N/A N/A 8.2 through B.6 systems closed OR inoperable.

e. Both pumps OR flowpath MODE 3 in 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s: MODE 5 within additional 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR backup 1 suppression available in inoperable from the intake structure to the distribution loop. 24 hours RESTORE OPERABILITY WITHIN 14 DAYS

2. Auxiliary Building Hall Post continuous Fire Watch with backup PreAction System suppression within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 1

(Detection Zone 12)

3. CCW Room Wet Pipe Sprinkler Post continuous Fire Watch with backup 1

suppre ssion within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months System (Detection Zone 5)

4. CV Electrical Penetration Pre-Action Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months initiate inspections once per 2

shift System RCP Bays A, B, and C Pre-Action Refer to FP-012 2

5.

System

6. Fire Hose Stations F0rFH 31, 35, 52, 70, 78, 82, 83, 90, 93, 107, (Less Than FP-012) 122, 123, 124,125,126,127,128, 129, Hose House AND Hydrant FP-84 at Intake, within one hour, connect additional, equivalent capacity 2

hose suppression provided.

1. If necessary, add additional sheets describing backup stations are suspended.

2. During ILRT AND SIT, FP-012 Containment hose Rev. 85 Page 35 of 88 OMM-007

ATTACHMENT 10.3 Page 2 of 2 EIR FIRE WATER SYSTEMS Significant Maintenance Rule System FUNCTION C. IF an unplanned unavailability, AND a High Safety potential safety significant functional failure is affected by the equipment, THEN initiate CR stating a has occurred. CR #

D. Operating Limitations Date

1. Equipment declared inoperable: Time

2. Reason for Equipment lnoperability:_________________

d out of service time is NOTE: FP-012 states that an NCR shall be initiated if the allowe exceeded.

Section B:

3. Time equipment required to be returned to service lAW Time: Date:

(Fire Pump, Fire Hydrant/Fire Hose,

4. IF an impairment to an active Fire Protection System

, etc.) exceeds OR is expected to Sprinkler/Deluge System, Detection/Suppression System er OR Designee shall be notified within exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , THEN the RESS Fire Protection Engine one working day (ACR 94-01019):

Time: Date:

Person Contacted WR ____

WR initiated: (ACR 94-00281) 5.

g/water supply to SI, AFW, and NOTE: Only the main fire water pumps and the alternate coolin Rule unavai lability .

Charging Pumps are monitored for Maintenance d, THEN record Allowed Unavailability Hours,

6. IF a Maintenance Rule System Function is affecte Remaining.

Actual Unavailability Hours, and Unavailability Hours Allowed -

Hours Actual = Hours Remaining notify the RES Duty Manager.

IF unplanned and less than 72 Hours remaining, THEN Date Time Name

7. Completed By: Date SMICRS

8. Comments:

E. RESTORATION

1. Equipment Operable: Time Date

2. Completed By: Date SM/CRS Rev. 85 Page 36 of 88 OMM-007

ATTACHMENT 10.4 Page 1 of 2 FIRE BARRIERS EIR GASEOUS SUPPRESSION AND CONTINUOUS USE available.

This revision has been verified to be the latest revision Date NIT A. Equipment Inoperable:

B. Equipment to be Inoperable I Compensatory Actions COMPENSATORY ACTION ACTION INITIATED INOPERABLE EQUIPMENT TIME j DATE RESTORE OPERABILITY WITHIN 14 DAYS

1. CO Systems 2 a. For Cable Vaults, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months post a (EDG Room OR Cable Vaults) continuous Fire Watch with backup ssion 1

suppre

b. For EDG Room, establish hourly inspections. IF EDG operating, THEN post a continuous Fire Watch with backup suppression 1

2. Halon System Post continuous Fire Watch with backup (Zones 19 and 20) suppression within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months lAW FP-012.

1 RESTORE OPERABILITY WITHIN 7 DAYS

3. Fire Doors, Dampers, OR a. Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , check detection on both Penetration Seals 2 sides, as applicable.

b. IF either detection system is inoperable, THEN within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , post continuous Fire Watch on one side with backup suppression 1

c. For inoperable Fire Dampers, refer to FP-014 AND complete Item D.4 on next page.

4. CCW Pump Room Conduit Fire a. Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , check detection system for:

Wrap, EDGB SW Pipe CCW Pump Room Detection Zone 5 Insulation/Pipe Support EDG Room, Detection Zone 2 Coatings in EDG A Room, OR MCC-A AND MCC-B Sealed Battery Room Detection Zone 16 Conduit Stubs I Cabinet Covers IF applicable detection system is inoperable, THEN within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , post continuous Fire Watch with backup suppression 1

backup suppression provided.

1. If necessary, add additional sheets describing 9)

Room dampe rs, penetra tion seals, OR fire doors (FDR-17, FDR-48, FDR-4

2. Inoperability of Control and 3.7.10.

nce ITS 3.7.9 may disable Control Room HVAC System. Refere IF the inoper able dampe rs are closed AND in an EDG Room, THEN the associated EDG is FD-2 & 75; Zone 2: FD-5 & 7).

inoperable; reference ITS 3.8.1 and 3.8.2 (Zone 1:

Rev. 85 Page 37 of 88]

OMM-007

ATTACHMENT 10.4 Page 2 of 2 FIRE BARRIERS EIR GASEOUS SUPPRESSION AND cant Maintenance Rule System FUNCTION C. IF an unplanned unavailability, AND a High Safety Signifi stating a potenti al safety significant functional failure is affected by the equipment, THEN initiate CR has occurred. CR #

D. Operating Limitations

1. Equipment declared inoperable: Time Date

2. Reason for Equipment Inoperability:

NOTE: FP-012 states that an NCR shall be initiated if the allowed out of service time is exceeded.

n B:

3. Time equipment required to be returned to service lAW Sectio Time:

Date:

lAW FP-014:

4. IF an inoperable damper, THEN actions have been taken Time:

Date: Initials:

Pump, Fire HydrantlFire Hose,

5. IF an impairment to an active Fire Protection System (Fire ion/Su ppress ion System , etc.) exceeds OR is expected to Sprinkler/Deluge System, Detect er OR Designee shall be notified within exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , THEN the RESS Fire Protection Engine one working day (ACR 94-01019):

Time: Date:

Person Contacted WR ___

WR initiated: (ACR 94-0028 1) 6.

7. Completed By: Date SM/CRS

8. Comments:

E. RESTORATION

1. Equipment Operable: Time Date

2. Completed By: Date SM/CRS Rev. 85 Page 38 of 88 OMM-007

10.5 ATTACHMENT Page 1 of 2 EIR MISCELLANEOUS FIRE PROTECTION EQUIPMENT CONTINUOUS USE n available.

This revision has been verified to be the latest revisio Date NIT A. Equipment Inoperable:

s B. Equipment to be Inoperable I Compensatory Action COMPENSATORY ACTION ACTION INITIATED INOPERABLE EQUIPMENT TIME DATE ENSATORY ACTION IS NOT AVAILABLE, THEN IF THE MINIMUM EQUIPMENT IDENTIFIED BY THE COMP RESTORE THE MINIM UM EQUIP MENT TO OPERABILITY WITHIN 14 DAYS Scott Air Packs and Cylinders Check at least:

10 SCBAs are operable.

10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months of air available in spare cylinders

2. Breathing Air Compressor Check the Cascade Cylinders are operable with pressure between 5100 and 6000 psig.

3. Cascade Cylinders Check the Breathing Air Compressor is operable OR six hours of air available in spare cylinders in addition to the 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months listed in step 1 above.

4. SCBA Fill Station Suspend unnecessary usage of breathing air.

Reference AP-038 for possible backup of air.

s source

5. Fire Brigade Radios Check at least nine (9) Fire Brigade radios are (Use Attachment 10.6, EIR operable.

DS / SBO Equipment And Other Equipment Important to Safety)

N/A N/A N/A

6. Motorized Emergency Response Cart (MERC)

Rev. 85 Page 39 of 88 OMM-007

ATTACHMENT 10.5 Page 2 of 2 IPMENT EIR MISCELLANEOUS FIRE PROTECTION EQU or OMM-048 evaluation.

C. This section is not applicable to the Maintenance Rule D. Operating Limitations

1. Equipment declared inoperable: Time Date

2. Reason for Equipment Inoperability:

lAW Section B:

3. Time equipment required to be returned to service atory Action is available.)

(N/A if minimum equipment identified by the Compens Time:

Date:

WR

4. WR initiated: (ACR 94-00281)

5. Completed By: Date SM/CRS

6. Comments:

E. RESTORATION

1. Equipment Operable: Time Date

2. Completed By: Date SM/CRS Rev. 85 Page 40 of 88 OMM-007

ATTACHMENT 10.6 Page 1 of 3 TO SAFETY EIR - DS I SBO EQUIPMENT AND OTHER EQUIPMENT IMPORTANT CONTINUOUS USE le.

This revision has been verified to be the latest revision availab Date INIT TS surveillances are NOTE: Items powered from PP-50 remain operable as long as their long as they are energiz ed and met. Specifically, these components are still operable as operating, even if the DS battery or DS UPS is inoper able.

blocking of the pathway OR a security A. IF a safe shutdown pathway is made inoperable due to

, THEN initiate an EIR.

door or gate will not allow access/egress for safe shutdown events wn pathway by a cold weather B. IF the inoperability is due to the blocking of a safe shutdo R Engineer, THEN the enclosure, AND the enclosure is approved by the Appendix y declared operable.

impairment may be exited AND the safe shutdown pathwa DS / SBO Equipment List: And C. Document Equipment Inoperable from Attachment 10.12, Other Equipment Important to Safety.

41)

D. Redundant Equipment / Temporary Provisions: (CR 97-019 ty immediately to IF D Deepwell Pump becomes unavailable, THEN Notify Securi implement Security Compensatory Actions.

Security

Contact:

(Print name)

REDUNDANT VULNERABILITIES DUE COMPENSATORY MEASURES NECESSARY EQUIPMENT TO INOPERABILITY AVAILABLE te: (CR 97-01 941)

E. The compensatory measures documented above are adequa SM/Manager-Operations Date Rev. 85 Page 41 of 88 OMM-007

ATTACHMENT 10.6 Page 2 of 3 IMPORTANT TO SAFETY EIR - DS I SBO EQUIPMENT AND OTHER EQUIPMENT cant Maintenance Rule System F. IF an unplanned unavailability, AND a High Safety Signifi stating a potential safety FUNCTION is affected by the equipment, THEN initiate an NCR significant functional failure has occurred. NCR #

G. Operating Limitations

1. Equipment declared inoperable: Time Date

2. Reason for Equipment Inoperability:

WR #

3. WR initiated: (ACR 94-00281)

I days

4. Time equipment allowed inoperable: (Circle one)

THEN notify On-Call Security

5. IF this EIR is for the TSC/EOF/PAP Diesel Generator, AND Emergency Planning personnel.

On-Call Security On-Call EP (Print name) (Print name) check at least nine Dedicated

6. IF this EIR is for the Dedicated Shutdown radios, THEN Shutdown radios are operable.

THEN the SMICRS shall verify

7. IF the equipment is NOT inoperable for scheduled work, re the following is stated on WR that a WR has been initiated and review the WR to ensu CRS/SM Initials (CR 95-2670): WR #

on Attachment 10.10.

NOTE: Priority 2 is the appropriate priority for equipment listed Appropriate priority Time allowed out of service raded Equipment is Important to Safety and should NOT be downg d, THEN record Allowed Unavailability

8. IF a Maintenance Rule System Function is affecte Remaining.

Hours, Actual Unavailability Hours, and Unavailability Hours Allowed - Hours Actual = Hours Remaining notify the RES Duty Manager.

IF unplanned and less than 72 Hours remaining, THEN Date Time Name

9. Completed By: Date SM/CRS

10. Comments:

Rev. 85 Page 42 of 88 OMM-007

ATTACHMENT 10.6 Page 3 of 3 TO SAFETY EIR - OS I SBO EQUIPMENT AND OTHER EQUIPMENT IMPORTANT H. Inoperability> 14 days 10.12, DS/SBO With less than the specified equipment listed on Attachment Safety , oper able when in MODE 1, 2, Equipment and Other Equipment Important to statu s within 14 days or 3 or4, the equipment must be restored to an operable submit a CR.

CR # (N/A if not applicable)

I. Restoration

1. Equipment operable: Time Date

2. Equipment no longer required due to plant conditions:

Time Date Reason:

3. Completed By: Date SM/CRS Rev. 85 Page 43 of 88 OMM-007

ATTACHMENT 10.7 Page 1 of 5 EIR CONTINUOUS CALORIMETRIC PROGRAM INSTRUMENTATION CONTINUOUS USE This revision has been verified to be the latest revision available.

Date INIT A. Equipment Inoperable:

B. Equipment to be Inoperable I Compensatory Actions: (CR 96-01631)

Perform one of the following:

d

Disable the input to the Continuous Calorimetric Program OR delete the affecte ERFIS point from scan.

PARAMETER LOOP INSTRUMENT ERFIS POINT TO BE COMPENSATORY TAG NUMBER DISABLED IN ACTION INITIATED CALORIMETRIC PROGRAM OR DELETED FROM SCAN DATE TIME Main Steam 1 PT-474 MSPO400A Pressure 1 PM-474A 1 PM-474D 1 PT-475 MSPO4OIA 1 PM-475A I PM-475C I P1476 MSPO4O2A I PM-476A 1 PM-476B 2 PT-484 MSPO42OA 2 PM-484A 2 PM-484B 2 PT-485 MSPO421A 2 PM-485A 2 PM-485B Rev. 85 Page 44 of 88 OMM-007

ATTACHMENT 10.7 Page 2 of 5 EIR - CONTINUOU S CALO RIMET RIC PROGRAM INSTRUMENTATION nued):

B. Equipment to be Inoperable / Compensatory Actions (Conti INSTRUMENT ERFIS POINT TO BE COMPENSATORY PARAMETER LOOP TAG NUMBER DISABLED IN ACTION INITIATED CALORIMETRIC PROGRAM OR DELETED FROM SCAN DATE TIME Main Steam 2 PT-486 MSPO422A Pressure 2 PM-486A 2 PM-486B 3 PT-494 MSPO44OA 3 PM-494A 3 PM-494D 3 PT-495 MSPO44IA 3 PM-495A 3 PM-495C 3 PT-496 MSPO442A 3 PM-496A 3 PM-496B Feedwater 1 TE-3004 FWTO4I 8A Temperature 2 TE-3005 FWTO438A 3 TE-3006 FWTO458A Feedwater 1 FT-476 FWFO4O3A Flow 1 FM-476B 1 FT-477 FWFO4O4A 1 FM-477B 2 FT-486 FWFO423A 2 FM-486B 2 FT-487 FWFO424A 2 FM-487B 3 FT-496 FWFO443A 3 FM-496B 3 FT-497 FWFO444A 3 FM-497B Rev. 85 Page 45 of 88 OMM-007

ATTACHMENT 10.7 Page 3 of 5 RAM INSTRUMENTATION EIR - CONTINUOUS CALORIMETRIC PROG s (Continued):

B. Equipment to be Inoperable I Compensatory Action iNSTRUMENT ERFIS POINT TO BE COMPENSATORY PARAMETER LOOP TAG NUMBER DISABLED IN ACTION INITIATED CALORIMETRIC PROGRAM OR DELETED FROM SCAN DATE TIME 2.6 and should also be tracked NOTE: Blowdown Flow is required by the ODCM using Attachment 10.1 Blowdown 1 FIT-i 328A MSF14O7A Flow 2 FIT-1328B MSF1427A 3 FIT-1328C MSF1447A Main Steam 1 FT-474 MSFO4O5A Flow 1 FM-474B 1 FT-475 MSFO4O6A 1 FM-475B 2 FT-484 MSFO425A 2 FM-484B 2 FT-485 MSFO426A 2 FM-4856 3 FT-494 MSFO445A 3 FM-494B 3 FT-495 MSFO446A 3 FM-495B Charainci N/A FT-i22 CHFO128A N/A FM-122A N/A TE-123 CHTO126A N/A TM-123 Letdown N/A FT-150 CHFO134A N/A FM-150 1 TE-4i2D RCTO4O4A RCS i TM-4i2P i TM-4i2 Rev. 85 Page 46 of 88 OMM-007

ATTACHMENT 10.7 Page 4 of 5 EIR - CONTINUOUS CALO RIMET RIC PROGRAM INSTRUMENTATION B. Equipment to be Inoperable / Compensatory Actions (Continued):

INSTRUMENT ERFIS POINT TO BE COMPENSATORY PARAMETER LOOP TAG DISABLED IN ACTION INITIATED NUMBER CALORIMETRIC PROGRAM OR DELETED FROM SCAN DATE TIME FWUFM Feedwater I Calculated FWT1 COlA Temperature I Calculated FWT2001A 2 Calculated FWTIOO2A 2 Calculated FWT2002A 3 Calculated FWT1003A 3 Calculated FWT2003A Feedwater I PT-1077A FWP1001A Pressure 1 FWP2001A 2 PT-1077B FWP1002A 2 FWP2002A 3 PT-I 077C FWP1003A 3 FWP2003A Feedwater 1 FE11O74A FWFIOO1A Flow 1 FWF2001A 2 FE11O74B FWF1002A 2 FWF2002A 3 FE11O74C FWFIOO3A 3 FWF2003A LEFM N/A CPU-A N/A LEFM N/A CPU-B N/A Rev. 85 Page 47 of 88 OMM-007

ATTACHMENT 10.7 Page 5 of 5 EIR CONTINUOUS CALO RIMET RIC PROGRAM INSTRUMENTATION C. IF an unplanned unavailability, AND a High Safety Significant Maintenance Rule System a potenti al safety FUNCTION is affected by the equipment, THEN initiate CR stating significant functional failure has occurred. CR #

D. Operating Limitations CAUTION Flow input per loop for the Since there is only one Feed Water temperature AND Blowdown become invalid if any of these calculation, the ERFIS Feed Flow Automatic Calorimetric results inputs become unavailable.

in each of the three loops, With one of the two redundant Feed Flow transmitters out of service results becom e invalid .

the ERFIS Feed Flow Automatic Calorimetric from scan or disabled:

1. Equipment declared inoperable OR the inputs were removed Time Date

2. Reason for Equipment Inoperability:

Date By:

eted Compl 3.

SM!CRS

4. Comments:

E. Restoration

1. Equipment operable: Time Date (Associated Continuous Calorimetric Progra m or ERFIS points may be restored)

2. Equipment no longer required due to plant conditions:

Time Date Reason:

3. Completed By: Date SM/CRS Rev. 85 Page 48 of 88 OMM-007

ATTACHMENT 10.8 Page 1 of4 EIR ULTIMATE HEAT SINK (UHS) FOR SERVICE WATER TEMPERATURE EXCEEDING 97°F CONTINUOUS USE This revision has been verified to be the latest revision available. INIT Date A. Entry into ITS LCO 3.7.8 REQUIRED ACTIONS for Service Water Temperature Exceeding 97°F: Time Date:

B. Operating Limitations:

once per hour

1. Verify Service Water temperature is less than or equal to 99 °F AND begin logging hourly Service Water temper ature per PPP-1 14.

e Water System

2. Within ONE HOUR verify the required cooling capacity of the Servic is maintained as follows AND record status in Auto Log:

a signed memo to the NOTE: Prior to exceeding 97 °F, Engineering should have provided step provid ing the current Control Room following review of the documents in the following calcula tions to ensure the revision status and any pending changes associated with the

°F have not been assumptions for operating with a Service Water temperature up to 99 affected.

g the calculation NOTE: Calculation revisions can be checked in PASSPORT by enterin checked. Any number, such as RNP-M/MECH-1 649, the same as procedures are for the calcula tion would be listed under the Pending associated pending changes Changes tab.

t the a) Perform the following to check document revision status agains Engineering memo:

1) IF PASSPORT is available, THEN using PASSPORT, verify the revisions of the following documents AND any pending changes against the calculations are the same as listed in the Engineering memo.

CM-201, Safety Related and Non-Safety Related Heat Exchanger Maintenance, for Heat Exchanger Tube Plugging Limits Calculation RNP-M/MECH-1 649 EDG Loading Calculation RNP-E-8.016 Rev. 85 Page 49 of 88 OMM-007

ATTACHMENT 10.8 Page 2 of 4 URE EIR ULTIMATE HEAT SINK (UHS) FOR SERVICE WATER TEMPERAT EXCEEDING 97°F

2) IF PASSPORT is not available OR the document revision AND pending change status listed in PASSPORT does not agree with the Engineering memo, THEN contact the On-Call RESS Manager to ensure no revisions OR pending changes have been approved against the following documents which would invalidate the Engineering memo.

CM-201, Safety Related and Non-Safety Related Heat Exchanger Maintenance, for Heat Exchanger Tube Plugging Limits Calculation RNP-M/MECH-1 649 EDG Loading Calculation RNP-E-8.016 Initial Check Completed:

SM/CRS Date the b) Perform a review of plant logs, ElRs, and scheduled work activities since Engineering memo was initiated to assure any maintenance that was performed on heat exchangers supplied with Service Water for any of the following components DID NOT involve tube plugging AND that the components are OPERABLE.

Component Cooling Water Heat Exchanger A Component Cooling Water Heat Exchanger B Emergency Diesel A Emergency Diesel B HVH-1 HVH-2 HVH-3 HVH-4 Initial Check Completed:

SM/CRS Date Rev. 85 Page 50 of 88 OMM-007

ATTACHMENT 10.8 Page 3 of 4 EIR ULTIMATE HEAT SINK (UHS) FOR SERVICE WATER TEMPERATURE EXCEEDING 97°F 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND

3. IF one of the following occurs, THEN place the unit in MODE MODE 5 in 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months as required by ITS LCO 3.7.8:

14 Service Water temperature exceeds 99°F as measured by PPP-1 the Review of affected plant documents by Engineering identifies that ng up to 99 °F are no longer valid engineering assumptions for operati what is Review of revision status and pending changes is different than ined identified in the Engineering memo AND engineering has determ assumptions for operating up to 99 °F are no longer valid which invalidate Maintenance on any of the heat exchangers identified above engineering assumptions for operating up to 99 °F.

could force plant shutdown/load C. Load Dispatcher notified of REQUIRED ACTION which reduction. Initials ) [SOER 99-1, Rec. 1 C]

Schedule if plant shutdown D. Planning and Scheduling notified to develop Forced Outage anticipated. Initials) below AND in Auto Log:

E. Once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , perform the following AND record revisions of the following

1. Review memo supplied by Engineering AND verify the agains t the calcula tions to ensure they are the documents AND any pending changes same as listed in the memo.

ger CM-201, Safety Related and Non-Safety Related Heat Exchan Maintenance, for Heat Exchanger Tube Plugging Limits Calculation RNP-M/MECH-1 649 EDG Loading Calculation RNP-E-8.016 Date Time SM/CRS Signature Rev. 85 Page 51 of 88 OMM-007

ATTACHMENT 10.8 Page 4 of 4 EIR ULTIMATE

- HEAT SINK (UHS) FOR SERVICE WATER TEMPERATURE EXCEEDING 97°F is maintained by

2. Verify the required cooling capacity of the Service Water System performing a review of plant logs, EIRs and schedu led work activiti es for the previous 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to assure no maintenance was perform ed that would affect heat exchanger ied above for the initial check AND that OPERABILITY for the heat exchangers identif the components remain OPERABLE.

Date Time SM/CRS Signature F. Restoration

1. Exited ITS LCO 3.7.8 REQUIRED ACTIONS for Time Date Service Water Temperature Exceeding 97°F:

conditions:

2. ITS LCO 3.7.8 REQUIRED ACTIONS no longer required due to plant Time Date Reason:

3. Completed By:

SM/CRS Date Rev. 85 Page 52 of 88 OMM-007

ATTACHMENT 10.9 Page 1 of 2 KING REQUIRED EVENT TRAC CONTINUOUS USE This revision has been verified to be the latest revision available. INIT Date A. Affected Component:

B. Initiating Event: TIME________ DATE________

C. Required Surveillance/Event will terminate the

1. Describe the Surveillance/Event to be tracked and conditions which need for tracking:

2.

Reference:

________ DATE__________

3. First TIME and DATE the Surveillance/Event is due: TIME_

Rev. 85 Page 53 of 88 OMM-007

ATTACHMENT 10.9 Page 2 of 2 REQUIRED EVENT TRACKING Section C (Continued) track completion

4. IF the event being tracked will recur more than once, THEN record and in the table below:

Time/Date Time/Date Surveillance/Event SM/CRS Signature Surveillance/Event Completed is Required DATE__________

D. Completed By:

SM/C RS E. Restoration eted:

1. Required Surveillance/Event no longer required or actions compl TIME DATE_________

DATE

2. Completed By:

SM/CRS Rev. 85 Page 54 of 88 OMM-007

ATTACHMENT 10.10 Page 1 of 2 MAINTENANCE RULE SYSTEMS INFORMATION USE cant Systems under the The following systems are considered to be High Safety Signifi Maintenance rule.

1000 Containment lsol Valve Pseudo 5098 Dedicated Shutdown Diesel Generator System 1005 Reactor Vessel and Internals System 5100 Fuel Oil System 1045 Excore Nuclear Instrument System 5114 Dedicated Shutdown System 1065 Rod Control System 5120 Switchyard and Transformer System 1080 Reactor Protection and Safeguards 5170 4 KV AC Distribution System System 2005 Reactor Coolant System 5175 480V AC Distribution System 2045 Residual Heat Removal System 5185 208-120 VAC Distribution System 2060 Chemical and Volume Control System 5235 125V DC Battery/Charger/Distribution System Instrument Air System 0 2080 Safety Injection System 6135 6150 Nitrogen Supply/Blanketing System 3005 Steam Generator 3020 Main Steam 6175 Site Fire Protection System 3050 Feedwater System 6270 Primary and Demineralized Water Makeup System 3065 Auxiliary Feedwater 8010 Containment System 3070 Condensate System 8150 HVAC Containment Building System 4060 Service Water System 8210 HVAC Auxiliary Building 4080 Component/Cooling Water System 8220 HVAC Control Room Area 5095 Emergency Diesel Generator System Rev. 85 Page 55 of 88 OMM-007

ATTACHMENT 10.10 Page 2 of 2 MAINTENANCE RULE SYSTEMS nance rule:

The following systems require unavailability monitoring for the mainte System Whats Monitored 1065 Rod Drive Reactor trip breakers 2005 RCS RCS PORVs and block valves 2045 RHR RHR trains th 2060 CVCS Charging pump trains, boric acid pumps, emergency boration flowpa 2080 SI SI Pump trains, CV Spray trains, Accumulators 3020 MS SIG PORVs, Steam Supplies to SDAFW 3065 AFW AFW Pump trains, injection lines e

4060 SW SW pumps, SW booster pumps, north and south headers, Turbin Building Isolation 4080 CCW CCW pump trains, heat exchangers 5095 EDG EDG trains 5098 DSDG Dedicated Shutdown Diesel 5114 DS DS bus, DS-UPS-Inverter 51704 KV Auto Bus Transfer breakers 5175 480 V Bus E-1, Bus E-2 5185 120 I 208 VAC Constant voltage transformers 5235 125 VDC Battery Chargers, Inverters, DC Buses 6004 ERFIS ERFIS Computer 6135 IA Compressors, Backup Air Supply For Charging Pumps 6175 FP Pumps, Flowpath to SI, AFW, CVCS Pump cooling I suction 6270 Primary Water Deep Well Pump D, Primary Water Pumps and Header 8150 CV HVAC HVH units pe 8220 MCR HVAC Ventilation fans, Emergency Filtration Unit, Control Room Envelo Integrity Rev. 85 Page 56 of 88 OMM-007

ATTACHMENT 10.11 Page 1 of4 LOSS OF SAFETY FUNCTION WORKSHEET

[CAPR 193057]

CONTINUOUS USE in NOTE: The numbers in the flow chart correspond to the description of SFD steps ApPe C of the TRM.

NO DETERMINE THE IMPACT THE INOPERABILITY HAS ON APPLICABLE SUPPORTED FEATURES DOES THE

8. SUPPORT FEATURE DETERMINE THE IMPACT TS ACTIONS REQUIRE THE INOPERAB ILITIES CASCADING TO THE HAVE ON ALL APPLICABLE SUPPORTED FEATURE(S)

SUPPORTED FEATURES TS ACTIONS?

10.

SFD IS COMPLETE. 6.

REVIEW THE SFD ANY ENTER THE TIME AN ADDITIONAL APPLICABLE TS INOPERABILITY OCCURS OR ACTIONS OF THE A SUPPORTED FEATURE IS SUPPORTED DECLARED INOPERABLE FEATURE TS AND REVIEW OTHER ACTION STATEMENTS IN EFFECT 11.

DOES A NO LOSF EXIST FOR THE SUPPORTED FEATURE TS?

YES Jr

14. IS.

12. REVIEW THE SFD ANY TIME ENTER THE APPLICABLE TS CALCULATE AND TRACK THE CALCULATE AND TRACK THE AN ADDITIONAL ACTIONS OF THE SUPPORTED MAXIMUM COMPLETION MAXIMUM COMPLETION INOPERABILITY OCCURS OR FEATURE TS. TIME TO RESTORE THE TIME TO RESTORE THE A SUPPORTED FEATURE IS SUPPORT FEATURE AND SUPPORT FEATURE AND DECLARED INOPERABLE.

ASSOCIATED SUPPORTED ASSOCIATED SUPPORTED FEATURE(S) TO OPERABLE FEATURE(S) TO OPERABLE STATUS.

STATUS Rev. 85 Page 57 of 88 OMM-007

ATTACHMENT 10.11 Page 2 of 4 LOSS OF SAFETY FUNCTION WORKSHEET This revision has been verified to be the latest revision available. INIT Date NOTE: This Safety Function Determination should be performed by a licensed Senior s occur or an ITS Reactor Operator and should be reviewed any time additional inoperabilitie Supported Feature is declared inoper able.

INIT

1) List inoperable ITS Support Feature.

Feature

2) IF inoperable ITS Support Feature does NOT result in ITS Supported inoperability, THEN perform the following:

a) N/A steps 3 through 8.

b) Sign and date.

c) Forward worksheet to SM for review.

shift, THEN d) IF the Support Feature will NOT be returned to service prior to end of attach completed worksheet to the EIR for the Suppo rt Featur e.

THEN file e) IF the Support Feature will be returned to service prior to end of shift, LOSF Worksheet in EIR notebo ok.

inoperability,

3) IF inoperable ITS Support Feature results in ITS Supported Feature THEN list inoperable ITS Supported Feature(s).

Rev. 85 Page 58 of 88 OMM-007

ATTACHMENT 10.11 Page 3 of 4 LOSS OF SAFETY FUNCTION WORKSHEET INIT ITS Actions,

4) IF support feature ITS Actions require cascading to Supported Feature(s)

THEN perform the following:

a) Enter applicable ITS Actions of Supported Feature(s) ITS.

b) N/A steps 5 through 8.

c) Signanddate.

d) Forward worksheet to SM for review.

e) Attach completed worksheet to the EIR for the Support Feature.

inoperabilities

5) IF any other ITS LCOs are NOT met, THEN determine the impact the have on all applicable Supported Features AND list.

the following:

6) IF there are NO redundant Supported Features inoperable, THEN perform a) N/A steps 7 and 8.

b) Sign and date.

c) Forward worksheet to SM for review.

d) Attach completed worksheet to the EIR for the Supported Feature.

the following:

7) IF a LOSE does NOT exist for the Supported Feature ITS, THEN perform ITS Support a) Calculate and record the maximum completion time to restore the Feature and associated ITS Suppo rted Featur e(s) to operab le status.

hrs+ hrs = hrs st 1

Support Feature Supported Featur e Max Compl etion b) N/A step 8.

c) Signanddate.

d) Forward worksheet to SM for review.

e) Attach completed worksheet to the EIR for the Supported Feature.

Rev. 85 Page 59 of 88 OMM-007

ATTACHMENT 10.11 Page 4 of 4 LOSS OF SAFETY FUNCTION WORKSHEET INIT

8) IF a LOSE exists for the Supported Feature ITS, THEN perform the following:

a) Calculate and record the maximum completion time to restore the ITS Support Feature and associated ITS Supported Feature(s) to operable status.

hrs+ hrs = hrs Support Feature Supported Featur e Max Compl etion b) Enter the applicable ITS LCO for the ITS Supported Feature or ITS LCO 3.0.3 as applicable.

c) Attach completed worksheet to the EIR for the Supported Feature.

Remarks:___________________________________________

Completed By: Date:

SRO Reviewed By: Date: -

SM Rev. 85 Page 60 of 88 OMM-007

ATTACHMENT 10.12 Page 1 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY INFORMATION USE DS I SBO EQUIPMENT LIST 52/BYA, Reactor Trip Bypass Breaker Train A 52/BYB, Reactor Trip Bypass Breaker Train B 52/RTA, Reactor Trip Breaker A 52IRTB, Reactor Trip Breaker B AFW-1, AFW Pump Suction from CST AFW-4, SDAFW Pump Suction AFW-7, SDAFW Pump Suction Vent AFW-17, SDAFW PUMP RECIRC AFW-1 8, SDAFW Pump Vent AFW-20, SDAFW Pump Discharge AFW-22, AFW Pump A and B Suction AFW-24, AFW Suction from SW Emergency Backup AFW-28, AFW Pump A Suction AFW-29, AFW Pump B Suction AFW-34, AFW Pump A Vent AFW-35, AFW Pump B Vent AFW-42, AFW Pump A Recirculation AFW-43, AFW Pump B Recirculation AFW-53, V2-16A Inlet Valve AFW-54, V2-16B Inlet Valve AFW-55, V2-1 6C Inlet Valve AFW-62, V2-1 6A Outlet Valve AFW-63, V2-1 6B Outlet Valve AFW-64, V2-1 6C Outlet valve AFW-104, AFW Pumps Suction from CST AFW-1 10, AFW Pump A Recirculation Valve AFW-1 11, AFW Pump B Recirculation Valve AFW-1 17, SDAFW Pump Self Cooling Supply Rev. 85 Page 61 of 88 OMM-007

ATTACHMENT 10.12 Page 2 of 27 Os I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST AFW-PMP-A, Aux. Feedwater Pump A AFW-PMP-A-O/C, AFW Pump A Oil Cooler AFW-PMP-B, Aux. Feedwater Pump B AFW-PMP-B-O/C, AFW Pump B Oil Cooler AFW-V2-14A, SDAFW Pump FW Discharge to SG A AFW-V2-14B, SDAFW Pump FW Discharge to SG B AFW-V2-14C, SDAFW PUMP FW DISCHARGE TO SG C AFW-V2-16A, AFW HEADER DISCHARGE TO SG A AFW-V2-16B, AFW HEADER DISCHARGE TO SG B AFW-V2-16C, AFW HEADER DISCHARGE TO SG C AFW-V2-20A, AFW HEADER SUCTION ISOLATION VALVE AFW-V2-20B, AFW HEADER SUCTION ISOLATION VALVE AUX PANEL DC, AUXILIARY PANEL DC (125V DC)

BACKUP-GP-A, BACKUP GROUP A HEATERS (PRESSURIZER)

BACKUP-GP-B, BACKUP GROUP B HEATERS (PRESSURIZER)

BAT-CHRGR-A, 125VDC BATTERY CHARGER A BAT-CHRGR-A1, I25VDC BATTERY CHARGER Al BAT-CHRGR-B, 125VDC BATTERY CHARGER B BAT-CHRGR-B1, I 25VDC BATTERY CHARGER B 1 C-47, CONDENSATE STORAGE TANK CONDENSER SUPPLY C-66, CONDENSATE STORAGE TANK DRAIN CC-701A, CC PUMP A SUCTION VALVE CC-701B, CC PUMP B SUCTION VALVE CC-701C, CC PUMP C SUCTION VALVE CC-703A, CC PUMP A DISCHARGE VALVE CC-.703B, CC PUMP B DISCHARGE VALVE CC-703C, CC PUMP C DISCHARGE VALVE CC-710, CC SURGE LINE STOP VALVE OMM-007 Rev. 85 Page 62 of 88

ATTACHMENT 10.12 Page 3 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST CC 712A, CC HX B INLET VALVE CC 712B, CC HX B OUTLET VALVE CC 713A, CC HX A INLET VALVE CC 71 3B, CC HX A OUTLET VALVE CC-716A, COOLING WATER INLET VALVE CC-716B, COOLING WATER INLET VALVE CC-71 8A, CC TO RCP A VALVE CC-718B, CC TO RCP B VALVE CC-718C, CC TO RCP C VALVE CC-728A, RCP A THERMAL BARRIER CC OUTLET STOP VALVE CC-728B, RCP B THERMAL BARRIER CC OUTLET STOP VALVE CC-728C, RCP C THERMAL BARRIER CC OUTLET STOP VALVE CC-728D, CC FROM RHR PUMP COOL CC-735, THERMAL BARRIER OUTLET VALVE CC-736, CC FROM RCP A, B, C THERMAL BARRIER VALVE CC-737C, CC TO CHARGING PUMPS A, B, & C CC-737D, CC FROM CHARGING PUMPS A, B, & C CC-746A, CC TO RHR HX A VALVE CC-746B, CC TO RHR HX B VALVE CC-748A, CC FROM RHR HX A BUTTERFLY VALVE CC-748B, CC FROM RHR HX B BUTTERFLY VALVE CC-749A, CC FROM RHR HX A VALVE CC-749B, CC FROM RHR HX B VALVE CC-769A, CC FROM RHR PUMP A SEAL COOLER CC-769B, CC FROM RHR PUMP B SEAL COOLER CC-781, CC TO SEAL WATER HX VALVE CC-784, CC FROM SEAL WATER HX THROTTLE VALVE CC-785, CC FROM SEAL WATER HX VALVE CC-794A, CC TO SI, CONT. SPRAY, & RHR PUMPS OMM-007 Rev. 85 Page 63 of 88

ATTACHMENT 10.12 Page 4 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST CC-794B, CC FROM SI, CONT. SPRAY, & RHR PUMPS CC-795E, CC TO SI PUMP A SEAL COOLER VALVE CC-795F, CC TO SI PUMP B SEAL COOLER VALVE CC-795G, CC TO SI PUMP C SEAL COOLER VALVE CC-795H, CC FROM SI PUMP A SEAL COOLER VALVE CC-795J, CC FROM SI PUMP B SEAL COOLER VALVE CC-795K, CC FROM SI PUMP C SEAL COOLER VALVE CC-825A, CC TO CHARGING PUMP C OIL COOLER CC-825C, CC TO CHARGING PUMP A OIL COOLER CC-825D, CC FROM CHARGING PUMP C OIL COOLER CC-825F, CC FROM CHARGING PUMP A OIL COOLER CC-927, CC TO RHR PUMP A COOLING CC-928, CC TO RHR PUMP B COOLING CCW-HTX-A, CCW HEAT EXCHANGER A CCW-HTX-B, CCW HEAT EXCHANGER B CCW-PMP-A, COMPONENT COOLING WATER PUMP A CCW-PMP-B, COMPONENT COOLING WATER PUMP B CCW-PMP-C, COMPONENT COOLING WATER PUMP C CF-31 1, AMINE TO S/G C F.W. INLET CF-312, AMINE TO S/G B F.W. INLET CF-313, AMINE TO S/G A F.W. INLET CHG-PMP-A, CHARGING PUMP A CHG-PMP-B, CHARGING PUMP B CHG-PMP-C, CHARGING PUMP C Charging Pump Speed Controller Backup Air Supply (LCV-1 1 5B Backup Air Supply)

COND-STRG-TNK, CONDENSATE STORAGE TANK CONTROL-GP, CONTROL GROUP HEATERS (PRESSURIZER)

CVC-200A, LETDOWN ORIFICE ISOLATION VALVE CVC-200B, LETDOWN ORIFICE ISOLATION VALVE CVC-200C, LETDOWN ORIFICE ISOLATION VALVE OMM-007 Rev. 85 Page 64 of 88

ATTACHMENT 10.12 Page 5 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST CVC-202A, HCV-121 OUTLET VALVE CVC-202B, HCV-121 INLET VALVE CVC-257, VCT RELIEF VALVE CVC-264, VCT TO DRAIN HEADER VALVE CVC-267, CHARGING PUMP C SUCTION VALVE CVC-268, CHARGING PUMP SUCTION LINE REFUELLING WATER SEL. VALVE CVC-269, CHARGING PUMP B SUCTION VALVE CVC-270, CHARGING PUMP A SUCTION VALVE CVC-277A, CHARGING PUMP C RECIRC. ROOT VALVE CVC-277B, CHARGING PUMP B RECIRC. ROOT VALVE CVC-277C, CHARGING PUMP A RECIRC. ROOT VALVE CVC-282, CHARGING LINE FLOW ISOLATION VALVE CVC-286, CHARGING PUMP C TO CHARGING LINE VALVE CVC-289, CHARGING PUMP B TO CHARGING LINE VALVE CVC-290, CHARGING PUMP A TO CHARGING LINE VALVE CVC-291, CHARGING PUMP A TO SEAL INJECTION VALVE CVC-293A, SEAL INJ. FILTER A OUTLET VALVE CVC-293B, SEAL INJ. FILTER A INLET VALVE CVC-297A, RCP A SEAL WATER FLOW CONTROL VALVE CVC-297B, RCP B SEAL WATER FLOW CONTROL VALVE CVC-297C, RCP C SEAL WATER FLOW CONTROL VALVE CVC-303A, RCP A SEAL LEAKOFF VALVE CVC-303B, RCP B SEAL LEAKOFF VALVE CVC-303C, RCP C SEAL LEAKOFF VALVE CVC-304A, RCP A#l SEAL RETURN FLOW FT-156A & B ISOL. VALVE CVC-304B, RCP A #1 SEAL RETURN FLOW FT-i 56A & B ISOL. VALVE CVC-304E, RCP A #1 SEAL RETURN FLOW FT-155A & B ISOL. VALVE CVC-304F, RCP A #1 SEAL RETURN FLOW FT-i 55A & B ISOL. VALVE Rev. 85 Page 65 of 88 OMM-007

ATTACHMENT 10.12 Page 6 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFET Y

DS I SBO EQUIPMENT LIST CVC-304J, RCP A #1 SEAL RETURN FLOW FT-154A & B ISOL. VALVE CVC-304K, RCP A #1 SEAL RETURN FLOW FT-i 54A & B ISOL. VALVE CVC-309A, HCV-i21 BYPASS CVC-3iOA, CHARGING TO LOOP A HOT LEG CVC-310B, CHARGING TO LOOP B COLD LEG CVC-311, AUXILIARY PRESSURIZER SPRAY VALVE CVC-31 2, CVC-3i OA BYPASS VALVE CVC-320, SEAL WATER RETURN FILTER OUTLET VALVE CVC-32i, SEAL WATER RETURN HX OUTLET VALVE CVC-356, BORIC ACID BLENDER BYPASS TO CHARGING PUMP SUCTION CVC-358, RWST TO CHARGING PUMP SUCTION VALVE CVC-361, SEAL WATER RETURN HX INLET VALVE CVC-362, SEAL WATER RETURN HX BYPASS VALVE CVC-365B, BORIC ACID BLENDER TO RWST CVC-380, SEAL WATER RETURN FILTER INLET VALVE CVC-38i, RCP SEAL WATER RETURN VALVE CVC-382, RCP SEAL RETURN LINE RELIEF VALVE CVC-387, EXCESS LETDOWN LINE STOP VALVE DA-18A, DG A UPPER AIR START INLET ISOLATION DA-18B, DG B UPPER AIR START INLET ISOLATION DA-22A, DG A LOWER AIR START INLET ISOLATION DA-22B, DG B LOWER AIR START INLET ISOLATION DG-A-GEN, GENERATOR FOR DIESEL GENERATOR A DG-B-GEN, GENERATOR FOR DIESEL GENERATOR B DP-A, DISTRIBUTION PANEL A (125VDC)

DP-A(DS), DISTRIBUTION PANEL A (125VDC) (DEDICATED SHUTDOWN)

DP-B, DISTRIBUTION PANEL B (125VDC)

DS CPR PANEL, DEDICATED SHUTDOWN CHARGING PUMP ROOM CONTROL PANEL OMM-007 Rev. 85 Page 66 of 88

ATTACHMENT 10.12 Page 7 of 27 Os i SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPOR TANT TO SAFETY DS I SBO EQUIPMENT LIST DS SEC CNT PNL, DEDICATED SHUTDOWN SECONDARY CONTROL PANEL DS-A(DS)-PWR, I25VDC POWER SUPPLY FOR DP-A(DS)

DS-BUS, 480V BUS DS DSDG FO TANK, DS DIESEL GENERATOR FUEL OIL TANK DSDG PNL, DSDG CONTROL PANEL (REMOTE)

DS-UPS-BATTERY, DEDICATED SHUTDOWN UPS BATTERY (1 25VDC)

DS-UPS-INVERTER, DEDICATED SHUTDOWN UPS INVERTER DSD-FO-PMP, DEDICATED SHUTDOWN DIESEL GENERATO R FUEL OIL PUMP DSD-GEN, DEDICATED SHUTDOWN DIESEL GENERATOR DSS-MAIN-XFMR, DEDICATED SHUTDOWN SYSTEM MAIN TRAN SFORMER DW-21, AFW SUCTION FROM DEEP WELL EMERGENCY BACK UP E-1,480V BUS E-1 E-2, 480V BUS E-2 EV-1702, RV1-1 SOLENOID VALVE EV-1 708, RVI-2 SOLENOID VALVE EV-1711, RV1-3 SOLENOID VALVE EV-4541, DSD FUEL OIL DAY TANK SUPPLY SOLENOID VALV E

FCV-478, FEED REG VALVE A FCV-479, FEED REG BYPASS A FCV-488, FEED REG VALVE B FCV-489, FEED REG BYPASS B FCV-498, FEED REG VALVE C FCV-499, FEED REG BYPASS C FCV-605, RHR HX BYPASS VALVE FCV-626, THERMAL BARRIER OUTLET VALVE FCV-1424, MDAFW PUMP A FLOW CONTROL VALVE FCV-1425, MDAFW PUMP B FLOW CONTROL VALVE FCV-1930A, SG A BLOWDOWN FLOW CONTROL OMM-007 Rev. 85 Page 67 of 88

ATTACHMENT 10.12 Page 8 of 27 Os I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPOR TANT TO SAFETY DS I SBO EQUIPMENT LIST FCV-1931A, SG B BLOWDOWN FLOW CONTROL FCV-1932A, SG C BLOWDOWN FLOW CONTROL FCV-1933A, SG A SAMPLE FLOW CONTROL FCV-1934A, SG B SAMPLE FLOW CONTROL FCV-1935A, SG C SAMPLE FLOW CONTROL FCV-6416, SDAFW PUMP DISCHARGE FLOW CONTROL VALV E

Fl-i 24, SEAL INJECTION FLOW TO RCP C Fl-i 27, SEAL INJECTION FLOW TO RCP B FI-130, SEAL INJECTION FLOW TO RCP A Fl-I 54B, RCP C #1 SEAL LEAKOFF LO RANGE INDICATOR Fl-i55B, RCP B#l SEAL LEAKOFF LO RANGE INDICATOR Fl-i 56B, RCP A #i SEAL LEAKOFF LO RANGE INDICATOR FI-605, RHR REGEN HX TOTAL FLOW FI-613, CCW COMPONENT COOLING LOOP FLOW IND Fl-660, CCW CHARGING PUMP FLOW INDICATOR FI-940, SI HOT LEG HEADER FLOW INDICATOR Fl-i 426A, AFW SDAFW FLOW TO SG A Fl-i 426C, AFW SDAFW FLOW TO SG C FIC-626, CCW RCP THERMAL BARRIER FLOW INDICATOR CCW RCP THERMAL BARRIER HI and LO FLOW ALARMS FIC-626A, CCW BYPASS FLOW FROM THERMAL BARRIER FIC-637, CCW RHR PUMP B FLOW INDICATOR CCW RHR PUMP B LO FLOW ALARM FIC-638, CCW RHR PUMP A FLOW INDICATOR CCW RHR PUMP LO FLOW ALARM FIC-658, CCW SI PUMP FLOW INDICATOR CCW SI PUMP LO FLOW ALARM FIC-i424, MDAFW PUMP A DISCHARGE FLOW IND CONTROLLER (INCLUDES VALVE POSITION INDICATING LIGHTS)

FIC-1425, MDAFW PUMP B DISCHARGE FLOW IND CONTROLLER (INCLUDES VALVE POSITION INDICATING LIGHTS)

FO-i9A, EDG FUEL OIL TRANSFER PUMP A INLET VALVE FO-19B, EDG FUEL OIL TRANSFER PUMP B INLET VALVE OMM-007 Rev. 85 Page 68 of 88

ATTACHMENT 10.12 Page 9 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFET Y

DS I SBO EQUIPMENT LIST FO-22A, EDG FUEL OIL TRANSFER PUMP A DISCHARGE VALVE FO-22B, EDG FUEL OIL TRANSFER PUMP B DISCHARGE VALVE FO-23A, DIESEL OIL DAY TANK A HEADER ISOLATION VALVE FO-23B, DIESEL OIL DAY TANK B HEADER ISOLATION VALVE FO-25A, DIESEL OIL DAY TANK A HEADER ISOLATION VALVE FO-25B, DIESEL OIL DAY TANK B HEADER ISOLATION VALVE FO-64, UNIT #2 FUEL OIL USAGE TOTALIZER DISCHARGE ISOLATION VALVE FO65, UNIT #2 FUEL OIL USAGE TOTALIZER SUCTION ISOLATION VALVE FO-125, DS FUEL OIL PUMP FIRST SUCTION VALVE FO-126, DS FUEL OIL PUMP SUCTION VALVE FO-129, EV-4540 INLET VALVE FO-1 31, EV-4540 OUTLET VALVE FO-138, DS FUEL OIL DAY TANK INLET VALVE FO-157, DS FUEL OIL SUPPLY CUTOFF VALVE FO-176A, DG FUEL OIL DAY TANK EV-1963A-1 INLET VALVE FO-176B, DG FUEL OIL DAY TANK EV-1963B-1 INLET VALVE FO-177A, DG FUEL OIL DAY TANK EV-1963A-2 INLET VALVE FO-177B, DG FUEL OIL DAY TANK EV-1963B-2 INLET VALVE FO-178A, DG FUEL OIL DAY TANK EV-1963A-1 OUTLET VALVE FO-178B, DG FUEL OIL DAY TANK EV-1963B-1 OUTLET VALVE FO-179A, DG FUEL OIL DAY TANK EV-1963A-2 OUTLET VALVE FO-179B, DG FUEL OIL DAY TANK EV-1963B-2 OUTLET VALVE FO-XFER-PMP-A, FUEL OIL TRANSFER PUMP A FO-XFER-PMP-B, FUEL OIL TRANSFER PUMP B FT-154B, CVCS RCP C #1 SEAL LEAKOFF LO RANGE TRANSMITTER FT-155B, CVCS RCP B #1 SEAL LEAKOFF LO RANGE TRANSMITTER FT-i 56B, CVCS RCP A #1 SEAL LEAKOFF LO RANGE TRANSMITTER FT-605, RHR REGEN. HX TOTAL FLOW TRANSMITTER FT-613, CCW COMPONENT COOLING LOOP FLOW TRANSMITTER FT-940, SIS LOOP B FLOW TRANSMITTER FT-1424, AFW PUMP A DISCHARGE FLOW TRANSMITTER OMM-007 Rev. 85 Page 69 of 88

ATTACHMENT 10.12 Page 10 of 27 Os I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY OS I SBO EQUIPMENT LIST FT-1425, AFW PUMP B DISCHARGE FLOW TRANSMITTER FT-1426A, AFW FLOW TRANSMITTER TO SG A FT-1426C, AFW FLOW TRANSMITTER TO SG C FW-6A, SIG A FEED REGULATOR BYPASS OUTLET VALVE FW-6B, S/G B FEED REGULATOR BYPASS OUTLET VALVE FW-6C, S/G C FEED REGULATOR BYPASS OUTLET VALVE FW-8A, S/G A INLET STOP CHECK FW-8B, S/G B INLET STOP CHECK FW-8C, S/G C INLET STOP CHECK FW-201, SG WLU ISOL TO AND FROM SG A FW-203, SG WLU ISOL TO AND FROM SG B FW-205, SG WLU ISOL TO AND FROM SG C FW-232, FULL FLOW RECIRCULATION ISOLATION VALVE HCV-121, CHARGING FLOW HCV-137, EXCESS LETDOWN FLOW VALVE HCV-758, RHR HX OUTLET FLOW TO COLD LEGS VALVE HVE-17, EDG ROOM B EXHAUST FAN HVE-18, EDG ROOM A EXHAUST FAN HVE-8A, BATTERY ROOM EXHAUST FAN A HVE-8B, BATTERY ROOM EXHAUST FAN B HVH-5A, CRDM COOLING FAN HVH-5B, CRDM COOLING FAN HVH-6A, HVH SAFETY INJECTION PUMP AREA COOLING UNIT HVH-6B, HVH SAFETY INJECTION PUMP AREA COOLING UNIT HVS-5, EDG ROOM B SUPPLY FAN HVS-6, EDG ROOM A SUPPLY FAN IA-291, INSTRUMENT AIR TO HCV-758 IA-292, INSTRUMENT AIR TO FCV-605 IA-297, HEADER STOP TO PORV STATION AND MSIVS IA-297A, IA STOP BEFORE IA-298 AND IA-424 OMM-007 Rev. 85 Page 70 of 88

ATTACHMENT 10.12 Page 11 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPOR TANT TO SAFETY DS I SBO EQUIPMENT LIST IA-298, INSTRUMENT AIR TO PORVS (BEFORE DRYER)

IA-299, INSTRUMENT AIR TO REMOTE PORV STATION IA-423, NITROGEN TO STEAM LINE PORVS IA-424, INSTRUMENT AIR TO REMOTE PORV STATION IA-425, INSTRUMENT AIR TO REMOTE PORV STATION IA-488, PHEUNMATIC SUPPLY TO SG PORV RV1-1 IA-490, PNEUMATIC SUPPLY TO SG PORV RV1-3 IA-492, PNEUMATIC SUPPLY TO SC PORV RV1-2 IA-633, PNEUMATIC SUPPLY TO SG PORV RV1-1 IA-634, PNEUMATIC SUPPLY TO SG PORV RV1-3 IA-635, PNEUMATIC SUPPLY TO SG PORV RV1-2 IA-3269, INSTRUMENT AIR TO PIC-477 UPPER I/P IA-3270, INSTRUMENT AIR TO PIC-477 LOWER I/P IA-3271, INSTRUMENT AIR TO P10-487 UPPER I/P IA-3272, INSTRUMENT AIR TO PIC-487 LOWER I/P IA-3273, INSTRUMENT AIR TO PIC-497 UPPER I/P IA-3274, INSTRUMENT AIR TO P10-497 LOWER I/P IA-3697A, PX-1361A ISOLATION VALVE IA-3697B, PX-1361B ISOLATION VALVE IA-3697C, PX-1361C ISOLATION VALVE INST-I, INSTRUMENT BUS 1 INST-2, INSTRUMENT BUS 2 INST-3, INSTRUMENT BUS 3 INST-4, INSTRUMENT BUS 4 INST-6, INSTRUMENT BUS 6 INST-7, INSTRUMENT BUS 7 INST-8, INSTRUMENT BUS 8 INST-9, INSTRUMENT BUS 9 INVERTER-A, INVERTER A (7.5 KVA)

INVERTER-B, INVERTER B (7.5 KVA)

OMM-007 Rev. 85 Page 71 of 88

ATTACHMENT 10.12 Page 12 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST LCV-115B, EMERGENCY MAKEUP TO CHARGING PUMP SUCT ION LCV-1 1 5C, VOLUME CONTROL TANK OUTLET VALVE LCV-460A, LETDOWN LINE STOP VALVE LCV-460B, LETDOWN LINE STOP VALVE LI-459A, PZR LEVEL- INDICATOR LI-459B, PZR LEVEL CHARGING PUMP STATION INDICATOR LI-459C, PZR LEVEL- AUX F.W. PUMP STATION INDICATOR LI-460, PZR LEVEL-INDICATOR LI-461, PZR LEVEL LI-474, CH I SG 1 NARROW RANGE LEVEL INDICATOR LI-475, CH II SG 1 NARROW RANGE LEVEL INDICATOR LI-476, CH III SG 1 NARROW RANGE LEVEL INDICATOR LI-477A, SG A WIDE RANGE LEVEL INDICATOR LI-477B, SG A WIDE RANGE LEVEL INDICATOR LI-484, CH I SG 2 NARROW RANGE LEVEL INDICATOR LI-485, CH II SG 2 NARROW RANGE LEVEL INDICATOR LI-486, CH III SG 2 NARROW RANGE LEVEL INDICATOR LI-487A, SG B WIDE RANGE LEVEL INDICATOR LI-487B, SG B WIDE RANGE LEVEL INDICATOR LI-494, CH I SG 3 NARROW RANGE LEVEL INDICATOR LI-495, CH II SG 3 NARROW RANGE LEVEL INDICATOR LI-496, CH III SG 3 NARROW RANGE LEVEL INDICATOR LI-497A, SG C WIDE RANGE LEVEL INDICATOR LI-497B, SG C WIDE RANGE LEVEL INDICATOR LI-607A-1, SG A WIDE RANGE LEVEL INDICATOR (DS)

LI-607A-2, SG A WIDE RANGE LEVEL INDICATOR (DS)

LI-607B-1, SG B WIDE RANGE LEVEL INDICATOR (DS)

LI-607B-2, SG B WIDE RANGE LEVEL INDICATOR (DS)

LI-607C-1, SG C WIDE RANGE LEVEL INDICATOR (DS)

LI-607C-2, SG C WIDE RANGE LEVEL INDICATOR (DS)

OMM-007 Rev. 85 Page 72 of 88

ATTACHMENT 10.12 Page 13of27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST LI-607D-2, PZR LEVEL LI-607D1, PZR LEVEL LI-1454A, CST LEVEL INDICATOR LI-1454B, CST LEVEL INDICATOR LI-1454C, CST LEVEL INDICATOR LIC-947, SIS RWST LEVEL INDICATING CONTROLLER LP-26, LIGHTING PANEL 26 LP-29, LIGHTING PANEL 29 LP-41, LIGHTING PANEL 41 (DSD LNCL MCC-24, COMPT. 2H)

LR-477 (PEN 1), MS STEAM GENERATORS WIDE RANGE LEVEL RECORDER LR-477 (PEN 2), MS STEAM GENERATORS WIDE RANGE LEVEL RECORDER LR-477 (PEN 3), MS STEAM GENERATORS WIDE RANGE LEVEL RECORDER LT-459, PRESSURIZER LEVEL TRANSMITTER LT-460, PRESSURIZER LEVEL TRANSMITTER LT-461, PZR LEVEL TRANSMITTER LT-474, MAIN STEAM S/G A NARROW RANGE LEVEL TRANSMITTER LT-475, MAIN STEAM S/G A WIDE RANGE LEVEL TRANSMITTER LT-476, MS SG A NARROW RANGE LEVEL TRANSMITTER LT-477, MAIN STEAM S/G A WIDE RANGE LEVEL TRANSMITTER LT-484, MAIN STEAM SJG B NARROW RANGE LEVEL TRANSMITTER LT-485, MAIN STEAM S/G B WIDE RANGE LEVEL TRANSMITTER LT-486, MS SG B NARROW RANGE LEVEL TRANSMITTER LT-487, MAIN STEAM S/G B WIDE RANGE LEVEL TRANSMITTER LT-494, MAIN STEAM S/G C NARROW RANGE LEVEL TRANSMITTER LT-495, MAIN STEAM S/G C WIDE RANGE LEVEL TRANSMITTER LT-496, MS SG C NARROW RANGE LEVEL TRANSMITTER LT-497, MAIN STEAM SIG C WIDE RANGE LEVEL TRANSMITTER LT-607A, DSD S/G A WIDE RANGE LEVEL TRANSMITTER (DEDICATED CHANNEL)

LT-607B, DSD S/G B WIDE RANGE LEVEL TRANSMITTER (DEDICATED CHANNEL)

LT-607C, DSD S/G C WIDE RANGE LEVEL TRANSMITTER (DEDICATED CHANNEL)

OMM-007 Rev. 85 Page 73 of 88

ATTACHMENT 10.12 Page 14 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST LT-607D, DSD PRESSURIZER LEVEL TRANSMITTER (DEDICATED CHANNEL)

LT-1454A, CONDENSATE STORAGE TANK LEVEL TRANSMITTER LT-1454B, CONDENSATE STORAGE TANK LEVEL TRANSMITTER LT-1454C, CONDENSATE STORAGE TANK LEVEL TRANSMITTER (DEDICATED CHANNEL)

MCC-1, MOTOR CONTROL CENTER #1(480 VAC)

MCC-5, MOTOR CONTROL CENTER #5(480 VAC)

MCC-6, MOTOR CONTROL CENTER #6 (480 VAC)

MCC-9, MOTOR CONTROL CENTER #9(208 VAC)

MCC-10, MOTOR CONTROL CENTER #10 (208 VAC)

MCC-24, MOTOR CONTROL CENTER #24 (DEDICATED SHUTDOWN)

(480 VAC)

MCC-A, I25VDC LOAD CENTER A MCC-B, 125VDC LOAD CENTER B MS-19, SG A STEAM LINE BEFORE SEAT DRAIN ROOT ISOL MS-28, SG B STEAM LINE BEFORE SEAT DRAIN ROOT ISOL MS-37, SG C STEAM LINE BEFORE SEAT DRAIN ROOT ISOL MS-i 54, STEAM TO AFW PUMP ISOLATION VALVE MS-262A, MS-Vi-8A INLET ISOLATION VALVE MS-262B, MS-V1-8B INLET ISOLATION VALVE MS-262C, MS-V1-8C IN LET ISOLATION VALVE MS-353A, MSIV Vi -3A BYPASS VALVE MS-353B, MSIV Vi-3B BYPASS VALVE MS-353C, MSIV Vi-3C BYPASS VALVE MS-353A, MSIVV1-3A BYPASS VALVE BREAKER (MCC-8 CMPT 1C) (Note 1)

MS-353B, MSIVV1-3B BYPASS VALVE BREAKER (MCC-8 CMPT 2C) (Note 1)

MS-353C, MSIVVI-3C BYPASS VALVE BREAKER (MCC-8 CMPT 3C) (Note 1)

MS-V1-3A, MAIN STEAM ISOLATION VALVE A MS-Vi-3B, MAIN STEAM ISOLATION VALVE B MS-V1-3C, MAIN STEAM ISOLATION VALVE C Note 1 Appendix R concern only when breaker is closed.

OMM-007 Rev. 85 Page 74 of 88

ATTACHMENT 10.12 Page 15 of 27 Os I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFET Y

DS I SBO EQUIPMENT LIST MS-V1-8A, SIG A STEAM SUPPLY VALVE TO SDAFW PUMP MS-V1-8B, SIG B STEAM SUPPLY VALVE TO SDAFW PUMP MS-V1-8C, SIG C STEAM SUPPLY VALVE TO SDAFW PUMP N-32, SOURCE RANGE NIS CHANNEL I DRAWER 32 N-51, REG GUIDE 1.97 EXCORE NEUTRON FLUX MON CH III NE-32, SOURCE RANGE NIS CHANNEL 32 DETECTOR NE-51, REG GUIDE 1.97 NIS CHANNEL III DETECTOR NE-52, REG GUIDE 1.97 NIS CHANNEL IV DETECTOR NI-32B, SOURCE RANGE NIS CH 32 COUNT RATE INDICATOR NI-32D, SOURCE RANGE NIS CH 32 START-UP RATE INDICATOR NI-51, SOURCE RANGE NIS COUNT RATE (REMOTE)

NI-51A, SOURCE RANGE NIS COUNT RATE (CHANNEL III)

NI-51B, WIDE RANGE NIS POWER INDICATOR (CHANNEL III)

NI-52A, SOURCE RANGE NIS COUNT RATE (CHANNEL IV)

NI-52B, WIDE RANGE NIS POWER INDICATOR (CHANNEL IV)

NS-116, NITROGEN FOR POST FIRE REPAIR OF HCV-758 AND FCV-605 OPP-3, NITROGEN SUPPLY VALVE OPP-4, NITROGEN SUPPLY VALVE OPP-24, TRAIN B ISOLATION VALVE OPP-25, TRAIN A ISOLATION VALVE OPP-26, TRAIN B ISOLATION VALVE OPP-27, TRAIN A ISOLATION VALVE OPP-28, TRAIN B IA-NITROGEN ISOLATION VALVE OPP-29, TRAIN A IA-NITROGEN ISOLATION VALVE PCV-3(OPP), TRAIN A NITROGEN REGULATOR VALVE PCV-4(OPP), TRAIN B NITROGEN REGULATOR VALVE PCV-455C, PRESSURIZER PORV PCV-456, PRESSURIZER PORV PCV-1093A, STEAM DUMP PRESSURE CONTROL VALVE (NITROGEN ACCUMULATOR)

PCV-1093B, STEAM DUMP PRESSURE CONTROL VALVE (NITROGEN ACCUMULATOR)

OMM-007 Rev. 85 Page 75 of 88

ATTACHMENT 10.12 Page 16 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFET Y

DS I SBO EQUIPMENT LIST PCV-1093C, STEAM DUMP PRESSURE CONTROL VALVE (NITROGEN ACCUMUL ATOR)

P1-402, RCS WIDE RANGE PRESSURE P1-455, PZR PRESSURE P1-457, PZR PRESSURE P1-474, CH I SG A STEAM PRESS INDICATOR P1-475, CH II SG A STEAM PRESS INDICATOR P1-484, CH I SG B STEAM PRESS INDICATOR P1-485, CH II SG B STEAM PRESS INDICATOR P1-494, CH I SG C STEAM PRESS INDICATOR P1-495, CH II SC C STEAM PRESS INDICATOR PI-607E-1, DS PZR PRESSURE PI-607E-2, DS PZR PRESSURE P1-612, CCW COMPONENT COOLING PUMP DISCHARGE PRESSURE INDICATOR P1-940, SI HEADER PRESS INDICATOR P1-943, SI HEADER PRESS INDICATOR P1-956, CV PRESSURE INDICATOR EXTENDED RANGE CHANNEL 1 P1-i 092, STEAM DUMP NITROGEN ACCUMULATOR PRESSURE INDICATOR P1-i 602A, SWBP A SUCTION PRESSURE GAUGE P1-i 602B, SWBP B SUCTION PRESSURE GAUGE P1-1616, NORTH SW HEADER PRESSURE INDICATOR PI-1619A, SW FROM CCW HEAT EXCHANGER A PRESSURE INDICATOR PI-1619B, SW FROM CCW HEAT EXCHANGER B PRESSURE INDICATOR P1-i 684, SOUTH SW HEADER PRESSURE INDICATOR PIC-477, MS S/C A STEAM LINE PRESSURE INDICATOR CONTROL FOR RV1-1 SECONDARY CONT. PNL. MS S/C A STEAM LINE PRESSURE INDICATOR PIC-487, MS S/C B STEAM LINE PRESSURE INDICATOR CONTROL FOR RV1-2 SECONDARY CONT. PNL. MS S/C B STEAM LINE PRESSURE INDICATOR PIC-497, MS S/G C STEAM LINE PRESSURE INDICATOR CONTROL FOR RV1-3 SECONDARY CONT. PNL. MS S/C C STEAM LINE PRESSURE INDICATOR OMM-007 Rev. 85 Page 76 of 88

ATTACHMENT 10.12 Page 17 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPOR TANT TO SAFETY DS I SBO EQUIPMENT LIST PP-50, I2OVAC POWER PANEL #50 (DEDICATED SHUTDOWN

)

PP-51, 48OVAC POWER PANEL IN 4KV SWITCHGEAR ROOM (DEDICATED SHUTDOWN)

PRy-i 806, CONTROL AIR TO SIG A PORV (RV1-1)

PRy-i 807, CONTROL AIR TO SIG C PORV (RV1-1)

PRy-i 808, CONTROL AIR TO SIC B PORV (RVI-i)

PT-402, RCS WIDE RANGE PRESSURE PT-455, PRESSURIZER PRESSURE PROTECTION TRANSMITT ER PT-457, PZR PRESSURE TRANSMITTER PT-474, SIG A PRESSURE PT-475, MS SC A STEAM PRESS TRANSMITTER PT-484, SIG B PRESSURE PT-485, MS SG B STEAM PRESS TRANSMITTER LOOP 2 PT-494, S/G C PRESSURE PT-495, MS SG C STEAM PRESS TRANSMITTER PT-607E, DEDICATED SHUTDOWN PRESSURIZER PRESSURE TRANSMITTER PT-940, SIS HEADER PRESSURE TRANSMITTER PT-943, SIS HEADER PRESSURE TRANSMITTER PT-956, CV PRESSURE PT-1616, SW HDR PRESS TRANSMITTER PT-i 684, SW HDR PRESS TRANSMITTER PX-1361A, INST. AIR PRESSURE TEST CONNECTION FOR MS-V1

-3A PX-1 361 B, INST. AIR PRESSURE TEST CONNECTION FOR MS-Vi-3B PX-1 361 C, INST. AIR PRESSURE TEST CONNECTION FOR MS-V i-3C PX-16i5A, SERVICE WATER TO CCW HX A PRESSURE TEST POINT PX-i6i5B, SERVICE WATER TO CCW HX B PRESSURE TEST POINT PZR-RLF-TNK, PRESSURIZER RELIEF TANK RC-505A, DRAIN LINE ROOT ISOLATION VALVE RC-508A, LOOP B TO DRAIN LINE ROOT ISOLATION VALVE RC-5i5A, LOOP C TO DRAIN LINE ROOT ISOLATION VALVE RC-523, PRESSURIZER RELIEF TANK DRAIN TO RCDT PUMP VALV E

OMM-007 Rev. 85 Page 77 of 88

ATTACHMENT 10.12 Page 18 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPOR TANT TO SAFETY DS I SBO EQUIPMENT LIST RC-535, PCV-456 TO PRESSURIZER RELIEF LINE MOV RC-536, PCV-455C TO PRESSURIZER RELIEF LINE MOV RC-551A, PRESSURIZER RELIEF VALVE RC-551B, PRESSURIZER RELIEF VALVE RC-551C, PRESSURIZER RELIEF VALVE RC-567, HEAD VENT SOLENOID ISOLATION VALVE (REACTOR VESSE L)

RC-568, HEAD VENT SOLENOID ISOLATION VALVE (REACTOR VESSE L)

RC-569, PRESSURIZER VENT SOLENOID ISOLATION VALVE RC-570, PRESSURIZER VENT SOLENOID ISOLATION VALVE RC-571, PRT SOLENOID ISOLATION VALVE RC-572, CV ATMOSPHERE SOLENOID ISOLATION VALVE REGEN-HX, REGENERATIVE HEAT EXCHANGER RHR-743, RHR SYSTEM HEATUP LINE ISOLATION VALVE RHR-744A, RHR RETURN COLD LEGS VALVE RHR-744B, RHR RETURN COLD LEGS VALVE RHR-750, LOOP B HOT LEG TO RHR SYSTEM VALVE RHR-751, LOOP B HOT LEG TO RHR SYSTEM VALVE RHR-752A, RHR PUMP A SUCTION VALVE RHR-752B, RHR PUMP B SUCTION VALVE RHR-754A, RHR PUMP A DISCHARGE VALVE RHR-754B, RHR PUMP B DISCHARGE VALVE RHR-757A, RHR HX A INLET VALVE RHR-757B, RHR HX B INLET VALVE RHR-757C, RHR HX A BYPASS ISOLATION VALVE RHR-757D, RHR HX B BYPASS ISOLATION VALVE RHR-759A, RHR HX A DISCHARGE VALVE RHR-759B, RHR HX B DISCHARGE VALVE RHR-760, RHR SYSTEM TO LETDOWN VALVE RHR-764, HCV-758 BYPASS VALVE OMM-007 Rev. 85 Page 78 of 88

ATTACHMENT 10.12 Page 19 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPOR TANT TO SAFETY OS I SBO EQUIPMENT LIST RHR-HTX-A, RHR HEAT EXCHANGER A RHR-HTX-B, RHR HEAT EXCHANGER B RHR-PMP-A, RHR PUMP A RHR-PMP-B, RHR PUMP B RV1-1, SIG A STEAM LINE PORV RV1-2, S/G B STEAM LINE PORV RV1-3, SIG C STEAM LINE PORV RWST, REFUELING WATER STORAGE TANK SDAFW-PMP, STEAM DRIVEN AUXILIARY FEEDWATER PUMP SDAFW-PMP-O/C, SDAFW PUMP OIL COOLER SDN-6, PCV-1093A INLET VALVE (STEAM DUMP NITROGEN ACCUMULATOR)

SDN-7, PCV-1093B INLET VALVE (STEAM DUMP NITROGEN ACCU MULATOR)

SDN-8, PCV-1093C INLET VALVE (STEAM DUMP NITROGEN ACCU MULATOR)

SDN-9, PCV-1093A OUTLET VALVE (STEAM DUMP NITROGEN ACCUMULATOR)

SDN-10, PCV-1093B OUTLET VALVE (STEAM DUMP NITROGEN ACCUMULATOR)

SDN-1 1, PCV-1 0930 OUTLET VALVE (STEAM DUMP NITROGEN ACCUMULATOR)

SDN-1 3, NITROGEN BACKUP SUPPLY (TO S/G PORV CONTROLL ERS)

SDN-28, NITROGEN BACKUP TO STEAM LINE PORVS (S/G PORV CONTROL)

SDN-29, STEAM DUMP PORV NITROGEN BACKUP TO IA TELL-TALE DRAIN SDN-30, PCV-1 019 INLET VALVE (NITROGEN TO MSIV ISOLATION)

SDN-ACCUM, STEAM DUMP NITROGEN ACCUMULATOR SEAL-WTR-HTX, SEAL WATER HEAT EXCHANGER SFPC-805A, RWP PUMP SUCTION FROM RWST SFPC-805B, RWST RETURN VALVE SG-A, STEAM GENERATOR A SG-B, STEAM GENERATOR B SG-C, STEAM GENERATOR C SI-837, RWST DRAIN SI-841A, BIT RECIRCULATION VALVE SI-856A, SI PUMP RECIRCULATION VALVE SI-856B, SI PUMP RECIRCULATION VALVE OMM-007 Rev. 85 Page 79 of 88

ATTACHMENT 10.12 Page 20 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPOR TANT TO SAFETY DS I SBO EQUIPMENT LIST SI-860A, CV SUMP RECIRC. SUCTION VALVE SI-860B, CV SUMP RECIRC. SUCTION VALVE SI-861A, CV SUMP RECIRC. SUCTION VALVE SI-861B, CV SUMP RECIRC. SUCTION VALVE SI-862A, RHR LOOP RWST ISOLATION VALVE SI-862B, RHR LOOP RWST ISOLATION VALVE SI-863A, RHR LOOP RECIRCULATION VALVE SI-863B, RHR LOOP RECIRCULATION VALVE SI-864A, RWST DISCHARGE VALVE Sl-864B, RWST DISCHARGE VALVE SI-865A, SI ACCUMULATOR A DISCHARGE VALVE SI-865B, SI ACCUMULATOR B DISCHARGE VALVE SI-865C, SI ACCUMULATOR C DISCHARGE VALVE SI-866A, RC LOOP C HOT LEG INJECTION VALVE SI-866B, RC LOOP B HOT LEG INJECTION VALVE SI-867A, BIT INLET VALVE SI-867B, BIT INLET VALVE SI-868A, HIGH HEAD TO LOOP C COLD LEG ISOLATION VALVE SI-868B, HIGH HEAD TO LOOP B COLD LEG ISOLATION VALVE SI-868C, HIGH HEAD TO LOOP A COLD LEG ISOLATION VALVE S1-869, LOOPS B AND C HOT LEG INJECTION SHUTOFF VALV E

SI-870A, BIT OUTLET VALVE SI-870B, BIT OUTLET VALVE SI-878A, SI PUMP DISCHARGE HEADER CROSS-CONNECT VALV E

SI-878B, SI PUMP DISCHARGE HEADER CROSS-CONNECT VALVE SI-880A, CV SPRAY PUMP A DISCHARGE VALVE SI-880B, CV SPRAY PUMP A DISCHARGE VALVE SI-880C, CV SPRAY PUMP B DISCHARGE VALVE SI-880D, CV SPRAY PUMP B DISCHARGE VALVE OMM-007 Rev. 85 Page 80 of 88

ATTACHMENT 10.12 Page 21 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY OS I SBO EQUIPMENT LIST SI-885, RHR PUMPS A AND B TO LOOPS CROSS CONNECT VALVE SI-886A, RWST TO SI PUMP A SUCTION SI-886B, RWST TO SI PUMP B SUCTION SI-886C, RWST TO SI PUMP C SUCTION SI-888A, SI PUMP A DISCHARGE VALVE SI-888B, SI PUMP B DISCHARGE VALVE SI-888C, SI PUMP C DISCHARGE VALVE SI-891C, RHR PUMP DISCHARGE TO SI PUMPS BAND C SI-891 D, RHR PUMP DISCHARGE TO SI PUMPS B AND C SI-892D, SPRAY ADDITIVE FLOW EDUCTOR TEST VALVE SI-895P, SI TEST LINE ISOLATION VALVE SI-895V, SI TEST LINE ISOLATION VALVE SI-928, CS PUMP B FULL FLOW TEST LINE ROOT ISOLATION SI-925, CS PUMP A FULL FLOW TEST LINE ROOT ISOLATION SI-898D, RWST LOCAL SAMPLE ISOLATION SI-898G, SI PUMP A MINIFLOW ISOLATION VALVE SI-898H, SI PUMP B MINIFLOW ISOLATION VALVE SI-898J, SI PUMP C MINIFLOW ISOLATION VALVE S1-932, SI PUMP A FULL FLOW TEST LINE ROOT ISOLATION SI-935, SI PUMP B FULL FLOW TEST LINE ROOT ISOLATION S1-938, SI PUMP C FULL FLOW TEST LINE ROOT ISOLATION S1-915, RHR PUMP A MINIMUM FLOW RECIRCULATION VALVE S1-916, RHR PUMP B MINIMUM FLOW RECIRCULATION VALVE SI-PMP-A, SAFETY INJECTION PUMP A SI-PMP-B, SAFETY INJECTION PUMP B SI-PMP-C, SAFETY INJECTION PUMP C STATION A, 125VDC BATTERY A STATION B, 125VDC BATTERY B SV1-IA, S/G A SAFETY VALVE SV1 -1 B, S/G B SAFETY VALVE SVI-1C, SIG C SAFETY VALVE OMM-007 Rev. 85 Page 81 of 88

ATTACHMENT 10.12 Page 22 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST SV1-2A, SIG A SAFETY VALVE SV1-2B, S/G B SAFETY VALVE SV1-2C, SIG C SAFETY VALVE SV1-3A, SIG A SAFETY VALVE SV1-3B, S/G B SAFETY VALVE SV1-3C, S/G C SAFETY VALVE SV1-4A, S/G A SAFETY VALVE SV1-4B, SIG B SAFETY VALVE SV1-4C, SIG C SAFETY VALVE SW-5, SW PUMP A DISCHARGE VALVE SW-6, SW PUMP B DISCHARGE VALVE SW-7, SW PUMP C DISCHARGE VALVE SW-8, SW PUMP D DISCHARGE VALVE SW-20, CCW HEAT EXCHANGER A SUPPLY VALVE SW-21, CCW HEAT EXCHANGER B SUPPLY VALVE SW-23, SW RETURN FROM AUXILIARY BUILDING SW-24, SOUTH SW HEADER SUPPLY TO SW BOOSTER PUMPS SW-25, NORTH SW HEADER SUPPLY TO SW BOOSTER PUMPS SW-28, SW BOOSTER PUMP A SUCTION VALVE SW-29, SW BOOSTER PUMP B SUCTION VALVE SW-52, SOUTH SUPPLY HEADER TO A TRAIN COMP. IN AUX. BLDG SW-53, SOUTH SUPPLY HEADER TO B TRAIN COMP. IN AUX. BLDG SW-79, HVH-6A SUPPLY VALVE SW-79A, HVH-6A AND AIR DRYER SUPPLY VALVE SW-80, HVH-6A RETURN VALVE SW-80A, HVH-6A AND AIR DRYER RETURN VALVE SW-81, HVH-6B SUPPLY VALVE SW-82, HVH-6B RETURN VALVE OMM-007 Rev. 85 Page 82 of 88

ATTACHMENT 10.12 Page 23 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST SW-83, DIESEL SUPPLY CROSS-CONNECT VALVE SW-85, TCV-i 660 INLET VALVE (DIG A)

SW-86, TCV-i 660 OUTLET VALVE (D/G A)

SW-88, DIESEL A RETURN VALVE SW-89, TCV-1661 INLET VALVE (D/G B)

SW-90, TCV-1661 OUTLET VALVE (D/G B)

SW-92, DIESEL B RETURN VALVE SW-i 09, MOTOR DRIVEN AFW PUMP A SUPPLY VALVE SW-i 10, INLET TO TCV-1 903A (MDAFW PUMP A)

SW-i 12, MOTOR DRIVEN AFW PUMP A SUPPLY VALVE SW-113, INLET TO TCV-1903B (AFW PUMP OIL COOLER)

SW-i 15, MOTOR DRIVEN AFW PUMPS A AND B RETURN SW-i 18, SW EMERGENCY BACKUP TO AFW SUCTION SW-246, TCV-1 902 INLET VALVE SW-25i, OIL COOLER OUTLET TO DRAIN SW-25iA, OIL COOLER OUTLET TO DRAIN SW-252, INSTRUMENT STOP & NORMAL OIL COOLER RETURN TO PUMP SW-253, NORMAL OIL COOLING RETURN TO PUMP SW-258, ROOT VALVE PX-i615B SW-259, NORMAL OIL COOLING SUPPLY FROM PUMP (SDAFW)

SW-260, ROOT VALVE PI-16i9B SW-269, ROOT VALVE PX-i615A SW-270, MOTOR DRIVER AFW PUMP A OUTLET VALVE SW-271, ROOT VALVE PI-1619A SW-284, MOTOR DRIVER AFW PUMP B OUTLET VALVE SW-510, SOUTH SUPPLY TO SI PUMPS SW-51 1, NORTH SUPPLY TO SI PUMPS SW-5i2, SI PUMP A SUPPLY VALVE OMM-007 Rev. 85 Page 83 of 88

ATTACHMENT 10.12 Page 24 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST SW-513, SI PUMP A RETURN VALVE SW-514, SI PUMP B SUPPLY VALVE SW-515, SI PUMP B RETURN VALVE SW-516, SI PUMP C SUPPLY VALVE SW-517, SI PUMP C RETURN VALVE SW-564, MOTOR DRIVEN AFW PUMPS A & B RETURN VALVE SW-739, CCW HEAT EXCHANGER A RETURN VALVE SW-740, CCW HEAT EXCHANGER B RETURN VALVE SW-741, CCW HX B AUX. BUILDING RETURN COMMON ISOLATION VALVE SW-900, SW SUPPLY TO AFW PUMP OIL COOLER SW-914, SW SUPPLY TO AFW PUMP OIL COOLER SW-PMP-A, SERVICE WATER PUMP A SW-PMP-B, SERVICE WATER PUMP B SW-PMP-C, SERVICE WATER PUMP C SW-PMP-D, SERVICE WATER PUMP D TCV-659A, CHARGING PUMP A TO OIL TEMP CONTROL VALVE TCV-659C, CHARGING PUMP C TO OIL TEMP CONTROL VALVE TCV-1 660, DIESEL A TEMP. CONTROL VALVE TCV-1 661, DIESEL B TEMP. CONTROL VALVE TCV-1 903A, MOTOR DRIVEN AFW PUMP A TEMP CONTROL VALVE TCV-1 903B, MOTOR DRIVEN AFW PUMP B TEMP CONTROL VALVE TE-133, CVCS RCP SEAL WATER RETURN TEMP. RTD TE-410, LOOP A WIDE RANGE COLD LEG TEMPERATURE RTD TE-412B1, RCS LOOP 1 DELTAT/T AVG. PROT. TEMP. HOT LEG TE-412B2, RCS LOOP I DELTAT/T AVG. PROT. TEMP. HOT LEG TE-412B3, RCS LOOP 1 DELTA TIT AVG. PROT. TEMP. HOT LEG TE-412D, RCS LOOP 1 DELTA TIT AVG. PROT. TEMP. COLD LEG TE-413-1, LOOP A WIDE RANGE HOT LEG TEMPERATURE RTD OMM-007 Rev. 85 Page 84 of 88

ATTACHMENT 10.12 Page 25 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST TE-420, LOOP B WIDE RANGE COLD LEG TEMPERATURE RTD TE-423, LOOP B WIDE RANGE HOT LEG TEMPERATURE RTD TE-430, LOOP C WIDE RANGE COLD LEG TEMPERATURE RTD TE-433, LOOP C WIDE RANGE HOT LEG TEMPERATURE RTD TE604A, RHR PUMP A DISCHARGE TEMP. RTD TE-604B, RHR PUMP B DISCHARGE TEMP. RTD TI-I 33, RCP SEAL WATER RETURN TEMP IND TI-410A, DS LOOP A T COLD TI-410B, DS LOOP A T COLD TI-41 2A, RCS LOOP A TAVG/DELTA T PROTECTION TI-413A, DS T HOT TI-413B, DS T HOT TI-413C, RCS LOOP A T HOT TEMP TI-420, DS LOOP B T COLD TI-423, DS LOOP B T HOT TI-430, DS LOOP C T COLD TI-433, DS LOOP C T HOT TR-604, RHR A & B PMPS DISCH & HTX OUTLET TEMP RECORDER V6-12A, SOUTH SERVICE WATER HEADER SUPPLY VALVE V6-12B, SW PUMP DISCHARGE HEADER CROSS-CONNECT VALVE V6-12C, SW PUMP DISCHARGE HEADER CROSS-CONNECT VALVE V6-12D, NORTH SERVICE WATER HEADER SUPPLY VALVE V6-16A, SW NORTH HEADER SUPPLY TO TURBINE BUILDING V6-16B, SW SOUTH HEADER SUPPLY TO TURBINE BUILDING V6-16C, SW ISOLATION TO TURBINE BUILDING VOL-CTRL-TK, VOLUME CONTROL TANK OMM-007 Rev. 85 Page 85 of 88

ATTACHMENT 10.12 Page 26 of 27 DS I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY DS I SBO EQUIPMENT LIST EMERGENCY LIGHTING ELS-1 ELS-3 THRU ELS-41 ELS-46 THRU ELS-58 ELS-60 THRU ELS-72 ELS-74 AND ELS-75 ELS-77 AND ELS-78 ELS-80 THRU ELS-88 ELS-90 THRU ELS-i 16 ELS-118 AND ELS-119 ELS-121 ELS-162 AND ELS-167 THRU ELS-175 ELS-192 AND ELS-193 ELS-195, ELS-196, AND ELS-197 EOF/TSC/PAP DIESEL GENERATOR SECURITY HIGH MAST LIGHTS 4 AND 6 RADIOS TRANSCEIVER LOCATED IN 4KV SWITCHGEAR ROOM, ALONG NORTH WALL DEDICATED SHUTDOWN RADIOS (MINIMUM OF NINE (9) OPERABLE FOR DEDICATED SHUTDOWN).

U2 CONTROL ROOM CELLULAR PHONE COMMUNICATIONS WITH U-i CONTROL ROOM OMM-007 Rev. 85 Page 86 of 88

ATTACHMENT 10.12 Page 27 of 27 Os I SBO EQUIPMENT LIST AND OTHER EQUIPMENT IMPORTANT TO SAFETY INOPERABLE COMPONENT AFFECT ON EMERGENCY PROCEDURE CROSS-REFERENCE SAFETY INJECTION Component EPPs, SUPPs & AOPs Affected FRPs Affected Identification Foldouts Affected FI-943 EPP-9, EPP-15 AOP-013, AOP-020, FRP-C.1, FRP-C.2, AOP-029, AOP-033 FRP-C.3, FRP-H.1 RESIDUAL HEAT REMOVAL Component EPPs, SUPPs & ]ZPs Affected FRPs Affected Identification Foldouts Affected I______________________

FI-605 EPP-9, EPP-1O AOP-013, AOP-016, FRP-C.1, FRP-C.2, AOP-020, AOP-029, FRP-C.3, FRP-J.2 AOP-033 BORIC ACID & PRIMARY WATER Component EPPs, SUPPs & AOPs Affected FRPs Affected Identification Foldouts Affected Fl-lb EPP-4, EPP-7 AOP-003, AOP-004, FRP-S.1 AOP-035 OTHER COMPONENTS IMPORTANT TO SAFETY Instrument Air Compressors (IA-CMP-A, Any credited DS Pathway IA-CM P-B, IA-CMP-D) and Primary Air Compressor (IA-PRI-CMP)

Primary Water Pumps Primary Water Header NOTE: Minimum fuel oil supply is 2000 gallons in one or both Alternate Fuel Oil Storage Tanks.

A Alternate Fuel Oil Storage Tank B Alternate Fuel Oil Storage Tank NOTE: Security compensatory actions are required within one hour of D Deep Well Pump becoming unavailable. A Temporary Modification to install the Skid Diesel must be in place within 14 days of D Deep Well Pump becoming unavailable. Information on installation and operation of the Skid Diesel may be found in EC 59128 and SP-1517.

D Deep Well Pump OMM-007 Rev. 85 Page 87 of 88

ATTACHMENT 10.13 Page 1 of 1 FLOWCHART FOR INOPERABLE ITSITRMIODCMIRG 1.97 COMPONENTS THAT WILL BE RETURNED TO SERVICE PRIOR TO END OF SHIFT

[CAPR 193057]

REFERENCE USE NOTE: Refer to Section 8.9 for further guidance as needed.

OMM-007 Rev. 85 Page 88 of 88

Maintenance Rule Event List System 4080 RNP EventDate End Date Event Title Monitoring

7i EVENT 7/29/2010 7/29/2010 CCW-PMP-A-MTR TAKEN OOS TO LUBRICATE MOTO R BEARI CCW Pump Train A UNAVAILABLE HOURS 8/25/2010 8/25/2010 CCW-PMP-A Taken OOS for oil sample 5.53 CCW Pump Train A UNAVAILABLE HOURS 1/14/2011 1/14/2011 CCW-PMP-A taken OOS for oil sample 7.10 CCW Pump Train A UNAVAILABLE HOURS 5/31/2011 5/31/2011 CCW-PMP-A taken OOS for oil and oiler change 4.01 CCW Pump Train A UNAVAILABLE HOURS 8/25/2011 8/25/2011 CCW-PMP-A OOS for planned maintenance 7.81 CCW Pump Train A UNAVAILABLE HOURS 9/12/2011 9/14/2011 CCW-PMP-A unavailable due to DS bus outage 4.11 CCW Pump Train A UNAVAILABLE HOURS 53.06 81.62 7/27/2010 7/27/2010 CCW-PMP-B TAKEN OOS TO LUBRICATE MOTOR BEAR INGS CCW Pump Train B UNAVAILABLE HOURS 8/24/2010 8/24/2010 CCW-PMP-B Taken OOS for oil sample 7.75 CCW Pump Train B UNAVAILABLE HOURS 9/29/2010 10/1/2010 CCW-PMP-B Taken OOS to remove foreign material 2.73 CCW Pump Train B UNAVAILABLE HOURS 1/14/2011 1/14/2011 CCW-PMP-B taken OOS for oil sample 45.68 CCW Pump Train B UNAVAILABLE HOURS 1/22/2011 1/22/2011 CCW-PMP-B taken OOS for oil sample 3.88 CCW Pump Train B UNAVAILABLE HOURS 112312011 1/23/2011 CCW-PMP-B taken OOS for oil sample, follow-up 5.66 CCW Pump Train B UNAVAILABLE HOURS 2/12/2011 2/12/2011 CCW-PMP-B OOS for Oil Sample 3.20 CCW Pump Train B UNAVAILABLE HOURS 3/8/2011 3/8/2011 CCW-PMP-B OOS for OB bearing replacement 3.10 CCW Pump Train B UNAVAILABLE HOURS 3/9/2011 3/9/2011 CCW-PMP-B OOS for oil sample 10.50 CCW Pump Train B UNAVAILABLE HOURS 5/1 3/2011 5/13/2011 CCW-PMP-B taken OOS for oil flush and sample 2.63 CCW Pump Train B UNAVAILABLE HOURS 6/3/2011 6/3/2011 CCW-PMP-B taken OOS for oil change and sample 2.53 CCW Pump Train B UNAVAILABLE HOURS 8/25/2011 8/25/2011 CCW-PMP-B OOS for planned maintenance 3.48 CCW Pump Train B UNAVAILABLE HOURS 3.11 94.25 8/11/2010 8/11/2010 CCW-PMP-C taken OOS for oil sample and breaker inspections CCW Pump Train C UNAVAILABLE HOURS 9/12/2010 9/13/2010 CCW-PMP-C taken OOS to replace pump seals 6.41 CCW Pump Train C UNAVAILABLE HOURS 4/5/2011 4/7/2011 CCW-PMP-C taken OOS for seal leak, sleeve nut repair 33.41 CCW Pump Train C UNAVAILABLE HOURS 4/29/2011 4/29/2011 CCW-PMP-C taken OOS for oil sample 38.66 CCW Pump Train C UNAVAILABLE HOURS 6/14/2011 6/15/2011 CCW-PMP-C taken OOS, measurements for seal leakage 3.73 CCW Pump Train C UNAVAILABLE HOURS 8/15/2011 8/15/2011 CCW-PMP-C OOS for planned maintenance 19.13 CCW Pump Train C UNAVAILABLE HOURS 2.96 10/13/2011 Page 1

Event Date End Date Event Title Monitoring 104.30 5/7/2010 ONLINE GEMCO SWITCH REFURBISHMENT 1/CCW-C-MTR CCW Pump Train C 10/29/2010 CCW-PMP-C OOS to repair seal leak CCW Pump Train C 5/22/2010 CC-862F MAYBE CLOGGED System Integrity and Cooling Flowpath 5/29/2010 IMPLEMENT EC 63452 FOR CC-749A (CHILD EC 69284) System Integrity and Cooling Flowpath 6/30/2010 FIC-629 ON ERFIS INDICATES FLOW LO System Integrity and Cooling Flowpath 4/14/2011 MCC-5(3M)-42/C; ESTABLISH PICKUP/DROPOUT VOLTAGES System Integrity and Cooling Flowpath 10/13/2011 Page 2

Maintenance Rule Monitoring Status RNP 4080 Component/Cooling Water System Type 1__-____ 11iTi flTZ TF1 I.TI1 UNAVAILABILITY UNAVAILABLE HOURS 4111/2010 132 0 132 4 RELIABILITY FUNCTIONAL FAILURES 10/13/2008 1 0 1 4 UNAVAILABILITY UNAVAILABLE HOURS 4/11/2010 188 8162 106 4 RELIABILITY FUNCTIONAL FAILURES 10/13/2008 1 0 1 4 UNAVAILABILITY UNAVAILABLE HOURS 4/11/2010 132 94.25 38 4 RELIABILITY FUNCTIONAL FAILURES 10/13/2008 1 0 1 4 I

T [CCCW Iyjpp_TC

.JL -

UNAVAILABILITY UNAVAILABLE HOURS 4/11/2010 132 104.3 28 4 RELIABILITY FUNCTIONAL FAILURES 10/13/2008 1 0 1 4 RELIABILITY FUNCTIONAL FAILURES 10/13/2008 2 0 2 4

i(CWVaiveisoiat,on Motorin Status A2 RELIABILITY FUNCTIONAL FAILURES 10/13/2008 0 0 0 4

i[cystern7tejnt and COOIó,g paSU A2 i RELIABILITY FUNCTIONAL FAILURES 10/13/2008 1 0 1 4 10/13/2011 Page 1

MR PMG Monitoring Trend RNP 4080 ComponentfCooling Water System PMG: CCW Pump Train A Monitoring period (days): 550 Monitoring: UNAVAILABLE HOURS Allowable: 188 Goal: N Actual: 81.62 60 50 40 30 20 1:

I I I 1;i I I I I I I I p P%c %

1

% P

\ P\% %

I S cF 0° 4° ?

I PMG: CCW Pump Train B Monitoring period (days): 550 Monitoring: UNAVAILABLE HOURS Allowable: 132 Goal: N Actual: 94.25 50 45 40 35 30 25 20 15 10 5

0 I I f I I 10/13/2011 Page 1

MR PMG Monitoring Trend 4080 Component/Cooling Water System RNP PMG: CCW Pump Train C Monitoring: UNAVAILABLE HOURS Monito,ing period (days): 550 Goal: N Allowable: 132 Actual: 104.3 45, 40 35.

30 ,

25 10

. - p.

° i.N p.% p.. p.

10/13/2011 Page 2

Appendix C Job Performance Measure Form ES-C-I Worksheet Facility: HB ROBINSON Task No.:

Task

Title:

Perform Section 8.2.3 of OST-020, JPM No.: 2011-2 NRC JPM SRO Shiftly Surveillances A2 K/A

Reference:

G2.2.37 3.6 I 4.6 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discus s, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

Task Standard: Identify all out of specification readings and apply all applicable Technical Specification requirements.

Required Materials: OST-020 ITS General

References:

OST-020 Shiftly Surveillances, Revision 41 Handouts: OST-020 Initiating Cue: You have relieved the QAC on the 07-1 900 watch due to a sudden illness. He was performing but unable to complete OST-020, Shiftly Surveillances. Perform Section 8.2.3, evaluate the acceptability of the instrument readings, document any unsatisfactory conditions in the comments section of Attachment 10.1 and identify any applicable Technical Specifications requirements.

Time Critical Task: NO 2011-2 NRC JPM SRO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-I Worksheet Validation Time: 25 minutes 2011-2 NRC JPM SRO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 3 of II Form ES-C-I PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk)

Examiners Cue: Provide OST-020.

Performance Step: I Review procedure OST-020.

Standard: Reviews Precautions and Limitations and remainder of handout.

Examiners Note:

Comment:

Performance Step: 2 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.1)

1. PZR Level (Channels Ll-459A, 460 and 461)

Standard: Candidate compares the channel readings and determines that all channels are within 5% for PZR level.

Examiners Note:

Comment:

2011-2 NRC JPM SRO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 11 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 3 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.2)

2. PZR Pressure (Channels P1-455, 456 and 457)

Standard: Candidate compares the channel readings and determines that channel P1-455 is outside of the tolerance of 40 psig from the other 2 channels. ITS Table 3.3.2-1 Items 1 .d and 6.a apply for Mode 3. Condition D applies for Item 1 .d to Place the channel in trip within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or Be in Mode 4 within 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months . Condition H applies for Item 6.a to Verify the interlock is in the required state for existing unit condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in Mode 4 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months .

Examiners Note:

ITS Table 3.3.1-1, Items 7.a and 7.b do not apply. Item 7 is applicable in Modes I and 2. The unit is in Mode 3.

The interlock verification for PZR Pressure being greater than 2000 psig is the LO PRESS SI BLOCK PERMIT 2 X 2 status light is extinguished.

Comment:

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 5 of 1 1 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 4 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.3)

S/G Pressure for SIG A (Channels P1-474, 475 and 476)

SIG Pressure for SIG B (Channels P1-484, 485 and 486)

SIG Pressure for SIG C (Channels P1-494, 495 and 496)

Standard: Candidate compares the channel readings and determines that channel P1-484 is outside of the tolerance of 70 psig from the other 2 channels for S/G B. ITS Table 3.3.2-1 Items 1 .e, i .g and 4.e apply for Mode 3. Condition D applies for Items 1 .e, 1 .g and 4.e to Place the channel in trip within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or Be in Mode 4 within 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months .

Examiners Note:

ITS Table 3.3.3-1, Item 20 does not apply due to the required channels for steam generator pressure is 2 per SIG. The remaining channels for SIG B are operable and satisfy the specification.

Comment:

2011-2 NRC JPM SRO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 1 1 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 5 IF MODE 1, 2 CR3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.4)

SIG Level for S/G A (Channels Ll-474, 475 and 476)

S/G Level for SIG B (Channels Ll-484, 485 and 486)

S/G Level for SIG C (Channels Ll-494, 495 and 496)

Standard: Candidate compares the channel readings and determines that channel Ll-475 is outside of the tolerance of 5% from the other 2 channels for SIG A. ITS Table 3.3.8-i Item 1 applies for Mode 3.

Condition C applies for Item 1 to Place the channel in trip within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or Be in Mode 4 within 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months .

Examiners Note:

ITS Table 3.3.1-1 Items 13 and 14 are applicable in Modes I and 2. The unit is in Mode 3.

ITS Table 3.3.3-1 Item 13 for Steam Generator Water Level (Narrow Range) does not apply due to the other 2 remaining SIG level channels are operable. The specification requires 2 per SIG.

Comment:

Performance Step: 6 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.5)

Steam Header Pressure (Channels Pl-464A, 466 and 468)

Standard: Candidate compares the channel readings and determines all of the Steam Header pressure channels are within the tolerance of 70 psig.

Examiners Note:

Comment:

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 7 of 1 1 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 7 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.6)

S/G Steam Flows for SIG A (Channels Fl-474 and 475)

SIG Steam Flows for SIG A (Channels F 1-484 and 485)

SIG Steam Flows for SIG A (Channels Fl-494 and 495)

Standard: Candidate compares the channel readings and determines that all of the steam flow channels are within the specified tolerance.

Examiners Note:

Comment:

Performance Step: 8 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.7)

Tavg (Channels TI-412D, 422D and 432D)

Standard: Candidate compares the channel readings and determines that channel TI-432D is outside of the tolerance of 4°F from the other channels for Tavg. ITS Table 3.3.2-1 Items 1 .f, 4.d and 6.b apply for Mode 3. Condition D applies for Items 1 .f, 4.d and 6.b to Place the channel in trip within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or Be in Mode 4 within 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months . Condition H applies for Item 6.b to Verify the interlock is in the required state for existing unit condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in Mode 4 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months .

Examiners Note: The interlock verification for Tavg being greater than 543°F is the STEAM DUMP T-AVG CONTROL BLOCKED 2 X 2 status light is extinguished.

Comment:

2011-2 NRC JPM SRO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 8 of 1 1 Form ES-C-i PERFORMANCE INFORMATION Performance Step: 9 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.8)

SI Accumulator A Level (LI-920 and 922)

SI Accumulator B Level (LI-924 and 926)

SI Accumulator C Level (Ll-928 and 930)

Standard: Candidate compares the channel readings and determines all of the SI Accumulator level channels are within the tolerance of 5%.

Examiners Note:

Comment:

Performance Step: 10 IF MODE 1, 2CR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following: (Step 8.2.3.9)

SI Accumulator A Pressure (P1-921 and 923)

SI Accumulator B Pressure (P1-925 and 927)

SI Accumulator C Pressure (P1-929 and 931)

Standard: Candidate compares the channel readings and determines all of the SI Accumulator pressure channels are within the tolerance of 40 psig.

Examiners Note:

Comment:

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 9 of 1 1 Form ES-C-i PERFORMANCE INFORMATION END OF TASK Terminating Cue: When the instrument readings have been evaluated, comments made for any out of spec readings and the applicable Technical Specification requirements have been identified, the evaluation on this JPM is complete.

STOP TIME:

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 10 of 11 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM SRO A2 Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

2011-2 NRC JPM SRO A2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 1 1 of 1 1 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

INITIATING CUE: You have relieved the OAC on the 07-1900 watch due to a sudden illness. He was performing but unable to com plete OST 020, Shiftly Surveillances. Perform Section 8.2.3, evalu ate the acceptability of the instrument readings, document any unsatisfactory conditions in the comments section of Attachment 10.1 and identify any applicable Technical Specifica tions requirements.

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 11 of Ii Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS: The unit is in Mode 3 at 547°F and 2235 psig.

All MSIVs are open.

INITIATING CUE: You have relieved the OAC on the 07-1 900 watc h due to a sudden illness. He was performing but unable to com plete OST 020, Shiftly Surveillances. Perform Section 8.2.3

, evaluate the acceptability of the instrument readings, documen t any unsatisfactory conditions in the comments section of Attachment 10.1 and identify any applicable Technical Specifica tions requirements.

2011-2 NRC JPM SROA2 NUREG 1021, Revision 9, Supplement 1

Projres Energy Continuous Use H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 PLANT OPERATING MANUAL VOLUME 3 PART 9 OST-020 SHIFTL V SURVEILLANCES REVISION 41 OST-020 Rev. 41 Page 1 of 54

SUMMARY

OF CHANGES PRR 00453883 OST-020, Rev. 41 STEP REVISION COMMENTS 8.7.2.4.A Removed reference to the local wind up chart recorder. Changed the step wording from CHECK a value from a calibrated temperature instrument to a CHECK local temperature using a calibrated temperature instrument.

New NOTE Removed reference to the local wind up chart recorder. Changed the step prior to wording three instruments do not take temperatures to two instruments may step not take temperatures.

8.7.2.4.B 8.7.2.4.B Removed reference to the local wind up chart recorder.

8.7.2.8A Removed reference to the local wind up chart recorder. Changed the step wording from CHECK a value from a calibrated temperature instrument to a CHECK local temperature using a calibrated temperature instrument.

New NOTE Removed reference to the local wind up chart recorder. Changed the step prior to wording three instruments do not take temperatures to two instruments may step not take temperatures.

8.7.2.8.B 8.7.2.8B Removed reference to the local wind up chart recorder.

OST-020 Rev. 41 Page 2 of 54

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE 4

2.0 REFERENCES

4 3.0 RESPONSIBILITES 6 4.0 PREREQUISITES 6 5.0 PRECAUTIONS AND LIMITATIONS 6 6.0 SPECIAL TOOLS AND EQUIPMENT 8 7.0 ACCEPTANCE CRITERIA 8 8.0 PROCEDURE 9 8.1 Reactivity Control Systems 9 8.2 Instrumentation 11 8.3 Reactor Coolant System 28 8.4 Emergency Core Cooling Systems 41 8.5 Containment Systems 45 8.6 Plant Systems 46 8.7 Other 47 9.0 RECORDS 52 10.0 ATTACHMENTS 52 10.1 SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM (Shift 07-19) 53 10.2 SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM (Shift 19-07) 54 OST-020 Rev. 41 Page 3 of 54

1.0 PURPOSE 1.1 To provide instructions for performing ITS, TRM or ODCM required shiftly surveillances during Modes 1 through 5, AND REFER TO OST-020-1 ,for required shiftly surveillances during movement of irradiated fuel assemblies, DSC loading, Mode 6 and defueled operation.

THIS PROCEDURE HAS BEEN SCREENED lAW OPS-NGGC-1 306 AND DETERMINED NOT APPLICABLE TO THE REACTIVITY MANAGEMENT PROGRAM (PRR 00374090)

2.0 REFERENCES

2.1 Improved Technical Specifications (ITS) 2.2 OST-020-1, Shiftly Surveillances (Irradiated Fuel Movement, DSC Loading, Mode 6 and Defueled Operation) 2.3 OMM-015, Operations Surveillance Testing 2.4 OMM-001-11, Logkeeping 2.5 OP-006, Pressurizer PORV Pneumatic System/LTOPP 2.6 OMM-024, Rod Position Channel Check 2.7 OP-920, Radiation Monitoring System 2.8 PLP-100, Technical Requirements Manual (TRM) 2.9 ODCM, Offsite Dose Calculation Manual 2.10 EST-047, Reactor Coolant Flow Test 2.11 ESR 97-00601, Channel Check Tolerances for Steam Flow at Low Power Levels.

OST-020 Rev. 41 Page 4 of 54

2.12 ESR 97-00611, Rod Position Indication Drift 2.13 RNP-I/INST-1040, Revision 1, Main Steam Accuracy and Scaling Calculation 2.14 RNP-I/INST-1128, Revision 0, FT-424 Error/Uncertainty Calculation 2.15 8S19-P-101, Station Blackout Coping Analysis Report 2.16 CR 97-02328, SR 3.1.6.2 Documentation 2.17 GP-010, Refueling 2.18 ESR 99-00220, Alternate method of determining Seal Injection flow 2.19 EC 47162, Set-Points, Uncertainty CaIc change for Appendix K Uprate 2.20 LDCR 03-0002, Proposed change to LCO 3.1.7, Required Action A.1 2.21 NCR 188409, New Containment Analysis from Westinghouse 2.22 NCR290724, Black Creek Temperature Exceedance [CAPR]

2.23 RNP-l/INST-1127, LTOP Loop Uncertainty and Sealing Calculation (P-500 &

501)

OST-020 Rev. 41 Page 5 of 54

3.0 RESPONSIBILITES 3.1 Operations personnel are responsible for the performance, review and approval of this test.

3.2 Unit one Chemistry personnel is responsible for checking the local wind up chart recorder indication as required by plant procedure.

3.3 Unit one control room personnel is responsible for providing the Control Board Indication for Discharge Canal Weir temperature.

4.0 PREREQUISITES \J1T 4.1 This revision has been verified to be the latest revision available.

Date 4.2 The Shift Manager has given permission to conduct this test.

4.3 RECORD plant mode which shiftly checks are being performed.

(07-1 9)MODE (1 9-07)MODE 5.0 PRECAUTIONS AND LIMITATIONS 5.1 Any steps not applicable shall be marked N/A and the reason(s) noted in the COMMENTS section of Attachment 10.1 or 10.2.

5.2 This procedure has been screened lAW PLP-037 criteria and determined not applicable to PLP-037.

5.3 Steps within this procedure may be performed in any sequence, unless specified.

5.4 Steps may be done concurrently between watchstations.

OST-020 Rev. 41 Page 6 of 54

5.5 The following guidance does NOT apply to Steam Flow instruments when turbine load is less than 20% AND only applies to RTGB instrumentation. It is NOT intended to apply to instrumentation of different types sensing the same parameter (i.e., direct reading local pressure gauge shall NOT be compared against a pressure transmitter driving a remote meter): (CR 95-02700) 5.5.1 A deviation greater than 5% of full scale is used as the DOS limit. The instrument shall be declared OOS.

5.6 Steam Flow loops are pressure compensated to account for density changes in the steam that occur from low-load to full-load operation. The calibration of the loops are set up for optimum performance at 100% of rated flow. As a result, the performance of the loops at low flows is not as accurate, and can be operable but may not meet the 5% tolerance. Based on this information, the following should be used for channel check of the redundant Steam Flow instruments: (CR 95-02700) 5.6.1 IF Turbine load is less than or equal to 20%, THEN Steam Flow should be greater than 90% of indicated Feed Flow.

AND The tolerance between redundant Steam Flows should be within pph. (ESR 97-00601) 6 0.4xlO 5.6.2 IF Turbine load is greater than 20%, THEN the tolerance between redundant Steam Flow instruments should be within 5%.

5.6.3 If it appears that the 5% tolerance will not be met prior to exceeding 20%

Turbine load, THEN Engineering should be contacted to evaluate the specific situation.

5.7 A channel check can be performed when a redundant channel is unavailable (DOS). The qualitative check includes observation of the channel for unexplained changes that are not attributable to known activities such as changes in power level, filling, draining, heatup, cooldown, etc. Erratic behavior or unexplained changes in the channel indication would be conditions that would warrant declaring the channel DOS and applying the ITSITRM/ODCM required actions.

OST-020 Rev. 41 Page 7 of 54

6.0 SPECIAL TOOLS AND EQUIPMENT 6.1 IF NEEDED, THEN VERIFY the following test equi pment calibration is current AND RECORD the test equipment identification belo w:

Equipment Identification INIT Calibrated Thermometer 7.0 ACCEPTANCE CRITERIA 7.1 All steps for the applicable Mode have been complete d.

7.2 Performance of the surveillance satisfies the ITS, TRM and ODCM requirements and the OST should be considered SAT. IF the state d condition(s) is not met, THEN the applicable Action Statement is required to be entered.

7.3 The reviewing and approving authorities may accept this test lAW provisions set forth in OMM-015.

OST-020 Rev. 41 Page 8 of 54

Section 8.1 Page 1 of 2 8.0 PROCEDURE HIT KJIT 07-19 19-07 8.1 Reactivity Control Systems 8.1.1 IF MODE 1 OR 2 shiftly checks are required, THEN PERFORM the following:

1. VERIFY Individual Rod Positions are within alignment limits. (ITS SR 3.1.4.1)

2. VERIFY each Shutdown Bank is within the limits specified in the COLR. (ITS SR 3.1.5.1)

NOTE: When the Rod Insertion Limit monitor (APP-005-C5) is inoperable, ITS SR 3.1.6.2 requires the Control Bank position to be verified above the insertion limits specified in the COLR once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter. This can be performed by making an entry in the COs narrative log every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months referencing this SR number.

A WR should be initiated when comparisons between Analog Rod Position indication and bank demand position indication approach 7.5 inches.

3. VERIFY each Control Bank position is above the insertion limits specified in the COLR.

(ITS SR 3.1.6.2)

4. VERIFY Sequence and Overlap Limits specified in the COLR are met for Control Banks not fully withdrawn from the core. (ITS SR 3.1.6.3)

OST-020 Rev.41 Page9of54

Section 8.1 Page 2 of 2 8.1.1 (Continued)

INIT INIT 07-19 19-07

5. For bank demand position at or above 200 steps PERFORM CHANNEL CHECK by comparing Anal og Rod Position indication and bank demand position indication. (The individual rod position indication (RPI) shall be within +/-15 inches of the bank demand position)(ITS SR 3.1.7.1)

NOTE: OMM-024, Rod Position Channel Check, provides ERFIS is inoperable. applicable actions when The use of ERFIS is an acceptable alternate meth od for determining ARPI System Operability lAW Improved Tech Specs if the RTG B RPI indicators are not indicating properly. In cases where both indications (RPI and ERFIS) are tracking closely, and one of the indications is outside the required limits with the other indication still within the limits, ERFIS should be considered the most accu rate indication and actions taken should be based on the ERRS indication. If the ERF IS readout is used to replace the RPI indicators, it shall be continuously displayed on a terminal accessible to the Reactor Operator.

(ESR 97-00611)

A WR should be initiated when comparisons between ERFIS Individual Rod Position indication and bank demand position indication appr oach 7.5 inches.

6. For bank demand position at or above 200 steps, PERFORM CHANNEL CHECK by comparing ERR S

Individual Rod Position indication and bank demand position indication. (The ERFIS individua l

rod position indication shall be within +1-15 inches of the bank demand position)

OST-020 Rev. 41 Page 10 of 54

Section 8.2 Page 1 of 17 INIT INIT 07-19 19-07 8.2 Instrumentation 8.2.1 IF MODE 1 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following:

NOTE: The following check is to determine the deviation between the highest and lowest channel of redundant indicators for the same parameter. The redundant indicators to be compared are grouped in blocks. If the actual deviation is greater than the maximum allowed deviation as shown (deviation of 5% of the full range of the indicators movement), it is unacceptable.

1. RCS Flow (ITS SR 3.3.1.1, Table 3.3.1-1 Item 9.a and 9.b)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION NUMBER RANGE DEVIATION FI-414 0-120% 6% RNP-I/INST-1036 FI-4 15 FI-4 16 FI-424 0-120% 6% RNP-I/INST-1 036 FI-425 FI-426 FI-434 0-120% 6% RNP-I/INST-1036 FI-435 FI-436 OST-020 Rev. 41 Page 1 1 of 54

Section 8.2 Page 2 of 17 8.2.1 (Continued)

INIT INIT 07-19 19-07

2. Turbine Impulse Pressure (ITS SR 3.3.1.1, Table 3.3.1-1 Item 17.e)

INSTRUMEN INSTRUMENT MAXIMUM CALCULATION NUMBER T RANGE DEVIATION P1-446 0-900 psig 45 psig P1-447 RNP-I/INST-1045 8.2.2 IF MODE 1 OR 2 shiftly checks are required, THEN PERFO RM CHANNEL CHECK for the following:

NOTE: The following check is to determine the deviation between lowest channel of redundant indicators for the same para the highest and meter. The redundant indicators to be compared are grouped in blocks. If the actual deviation is greater than the maximum allowed deviation as shown (deviation of 5% of the full range of the indicators movement, except for SIG Feed Flow when <10% rated thermal power), it is unacceptable. (ESR 97-00601)

1. Overtemperature AT Setpoint (ITS SR 3.3.1.1, Table 3.3.1-1 Item 5)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION NUMBER RANGE DEVIATION TI-412C TI-422C WCAP 11889 0-75°F 4°F TI-432C

2. Overpower AT Setpoint (ITS SR 3.3.1.1, Table 3.3.1-1 Item 6)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION NUMBER RANGE DEVIATION TI-412B TI-422B WCAP 11889 0-75°F 4°F TI-432B OST-020 Rev. 41 Page 12 of 54

Section 8.2 Page 3 of 17 8.2.2 (Continued) INIT INIT 07-19 19-07

3. Loop Protection zT (ITS SR 3.3.1.1, Table 3.3.1-1 Item 5 and 6)

INSTRUMEN INSTRUMENT MAXIMUM CALCULATION T RANGE DEVIATION NUMBER TI-412A WCAP 11889 TI-422A 0-75°F 4°F TI-432A

4. S/C Feed Flow (ITS SR 3.3.1.1, Table 3.3.1-1 Item 14)

(ESR 97-00601)

IF10% rated thermal power, THEN check the following:

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER FI-476 0-4x1 06 pph 0.2x1 O pph 6 RNP-I/INST- 1041 FI-477 FI-486 6 pph 0-4x10 0.2xlO p

6 ph RNP-I/INST-1041 FI-487 FI-496 0-4x1 6 pph 0.2x1 Opph 6 RNP-I/INST-1 041 FI-497 IF <10% rated thermal power, THEN check the following:

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER FI-476 0-4x1 06 pph 0.4x1 O pph 6 RNP-I/INST-1 041 F 1-477 FI-486 0-4x1 06 pph 0.4x1 O pph 6 RNP-I/I NST-1 041 FI-487 FI-496 0-4x1 06 pph 0.4x1 O pph 6 RNP-I/INST-1 041 FI-497 OST-020 Rev. 41 Page 13 of 54

Section 8.2 Page 4 of 17 8.2.2 (Continued) INIT INIT 07-19 19-07 NOTE: Source Range Neutron Flux check is applicable in MODE 2.

Per Calculations RNP-I/INST-1 134, RNP-I/INST -1135, and Engineering determination from NCR 00268640, the following Channel Check Acceptance Criteria has been deemed appropriate for the Reactor Protection Source Range, Intermediate Range, and Power Range:

Power Range (N-41, N-42, N-43 and N-44): The acceptable deviation for the power range indication SHALL be within 2% power.

Intermediate Range: The logarithmic value of the lowest indication subtracted from the logarithmic value of the highest indication SHALL be S 1.78.

Source Range: The logarithmic value of the lowest indication subtracted from the logarithmic value of the highest indication SHALL be 5 1 .48.

Due to the difficulty in reading a logarithmic meter with a fluctuating signal, the digital indication from ERFIS or NR-45 should be used to perform the Channel Checks whenever possible.

The LOG function of an available calculator or the scientific calculator on the Control Room PC may be used to determine the logarithmic values. (NCR 268640)

5. Power Range Neutron Flux (ITS SR 3.3.1.1, Table 3.3.1-1 Item 2.a and 2.b):

a. PERFORM the following:

RECORD NI-41 indication % Power RECORD NI-42 indication % Power RECORD NI-43 indication % Power RECORD NI-44 indication % Power OST-020 Rev. 41 Page 14 of 54

Section 8.2 Page 5 of 17 8.2.2.5 (Continued) INIT INIT 07-19 19-07

b. CALCULATE maximum deviation:

Recorded (highest) minus Recorded (lowest) equals:

c. PEER CHECK calculation.

d. DOCUMENT results (within 2% power):

SAT! UNSAT (Circle One)

6. PERFORM the following:

RECORD Nl-41 indication._______ % Power RECORD Nl-42 indication._______ % Power RECORD Nl-43 indication % Power RECORD Nl-44 indication % Power

a. CALCULATE maximum deviation Recorded (highest) minus Recorded (lowest) equals:

b. PEER CHECK calculation.

c. DOCUMENT results (within 2% power):

SAT! UNSAT (Circle One)

OST-020 Rev. 41 Page 15 of 54

Section 8.2 Page 6 of 17 8.2.2 (Continued)

INIT INIT 07-19 19-07

7. Intermediate Range Neutron Flux (ITS SR 3.3.1.1, Table 3.3.1-1 Item 3)

a. RECORD NI-35 indication.

b. RECORD N-36 indication.

c. CALCULATE deviation:

LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results ( 1.78). SAT I UNSAT (Circle one)

OST-020 Rev. 41 Page 16 of 54

Section 8.2 Page 7 of 17 8.2.2 (Continued)

INIT INIT 07-19 19-07

8. Intermediate Range Neutron Flux (ITS SR 3.3.1.1, Table 3.3.1-1 Item 3)

a. RECORD NI-35 indication.

b. RECORD N-36 indication.

c. CALCULATE deviation:

LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results ( 1.78). SAT / UNSAT (Circle one)

9. (F required, THEN perform Source Range Neutron Flux check (if below P-6 Interlock)

(ITS SR 3.3.1.1, Table 3.3.1-1 Item 4)

a. RECORD NI-31 indication.

b. RECORD N-32 indication.

c. CALCULATE deviation:

LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results ( 1.48). SAT / UNSAT (Circle one)

10. IF required, THEN perform Source Range Neutron Flux check (if below P-6 Interlock)

(ITS SR 3.3.1.1, Table 3.3.1-1 Item 4)

a. RECORD NI-31 indication.

b. RECORD N-32 indication.

OST-020 Rev. 41 Page 17 of 54

Section 8.2 Page 8 of 17 8.2.2.10 (Continued) INIT lNlT 07-19 19-07

c. CALCULATE deviation: LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results ( 1.48). SAT / UNSAT (Circle one 8.2.3 IF MODE 1, 2, OR 3 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following:

NOTE: The following check is to determine the deviation between the highest and lowest channel of redundant indicators for the same parameter. The redundant indicators to be compared are grouped in blocks. If the actual deviation is greater than the maximum allowed deviation as shown (deviation of 5% of the full range of the indicators movement, except for S/G Steam Flow when <20% rated thermal power), it is unacceptable. (ESR 97-00601)

1. PZR Level (ITS SR 3.3.1.1, Table 3.3.1-1 Item 8 and ITS SR 3.3.3.1, Table 3.3.3-1 Item 12)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER LI-459A RNP-I/INST-1060 LI-460 0-100% 5%

LI-461 OST-020 Rev. 41 Page 18 of 54

Section 8.2 Page 9 of 17 8.2.3 (Continued) INIT INIT 07-19 19-07

2. PZR Pressure IF Pressurizer Pressure is outside the indicating range due to normal plant conditions, THEN mark N/A.

(ITS SR 3.3.1.1, Table 3.3.1-1 Item 7.a, 7.b and ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.d and 6.a)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION NUMBER RANGE DEVIATION P1-455 RNP-IIINST-1042 P1-456 1700-2500 psig 40 psig P1-457

3. S/G Pressure (ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.e, 1.g and 4.e, ITS SR 3.3.3.1, Table 3.3.3-1 Item 20)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER P1-474 RNP-I/INST-1072 P1-475 0-1400 psig 70 psig P 1-476 P1-484 RNP-I/INST-1072 P1-485 0-1400 psig 70 psig P 1-486 P1-494 RNP-IIINST-1072 P1-495 0-1400 psig 70 psig P1-496 OST-020 Rev. 41 Page 19 of 54

Section 8.2 Page 10 of 17 8.2.3 (Continued)

INJI iNil 07-19 19-07

4. S/G Level (ITS SR 3.3.1.1, Table 3.3.1-1 Item 13 and 14, ITS SR 3.3.3.1, Table 3.3.3-1 Item 13, ITS SR 3.3.8.1, Table 3.3.8-1 Item 1)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER LI-474 RNP-I/INST-1070 LI-475 0-100% 5%

LI-476 LI-484 RNP-I/INST-1070 LI-485 0-100% 5%

LI-486 LI-494 RNP-I/INST-1070 LI-495 0-100% 5%

LI-496

5. Steam Header Pressure (ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.e)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER PI-464A RNP-I/INST-1 050 P1-466 0-1400 psig 70 psig P1-468 OST-020 Rev. 41 Page 20 of 54

Section 8.2 Page 11 of 17 8.2.3 (Continued)

INIT INIT 07-19 19-07

6. SIG Steam Flow (ITS SR 3.3.1.1, Table 3.3.1-1 Item 14 and ITS SR 3.3.2.1, Table 3.3.2-1 Item if, 1.g, 4.d and 4.e) (ESR 97-00601)

IF 20% rated thermal power, THEN check the following:

INSTRUMENT INSTRUMENT RANGE [ MAXIMUM DEVIATION CALCULATION NUMBER Fl-474 0-4x1 06 pph 0.2x1 O pph 6 RNP-I/INST-1 040 Fl-475 FI-484 0-4x1 6 pph 0.2x1 O pph 6 RNP-I/INST-1 040 FI-485 FI-494 0-4x1 06 pph 0.2x1 O pph 6

F l-4 95 RNP-l/INST-1 040 IF <20% rated thermal power, THEN check the following:

INSTRUMENT INSTRUMENT RANGE MAXIMUM DEVIATION FI-474 6 pph 0-4x10 0.4x p

6 ph lO FI-475 between the following combinations:

FI-474 AND Fl-475

FI 474 AND FI-477

FI_475_AND_FI-476 FI-484 0-4x1 6 pph 0.4x1 O pph 6

FI-485 between the following combinations:

FI-484 AND FI-485

FI 484 AND Fl-487

Fl_485_AND_FI-486 F 1-494 0-4x1 6 pph 0.4x1 O pph 6

FI-495 between the following combinations:

Fl-494 AND Fl-495 99494 AND FI-497 99495 AND FI-496 The Steam Flow Channel is checked against the correspon ding Feed Flow channel for acceptance.

OST-020 Rev. 41 Page 21 of 54

Section 8.2 Page 12 of 17 8.2.3 (Continued)

INIT INIT 07-19 19-07

7. Tavg IF Tavg is outside the indicating range due to normal plant conditions, THEN mark N/A.

(ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.f, 4.d and 6.b)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER TI-412D TI-422D WCAP 11889 540-615°F 4°F TI-432D

8. SI Accumulator Level (TRMS TR 4.2.1)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER LI-920 0-100% 5% RNP-I/INST-1 052 LI-922 LI-924 0-100% 5% RNP-I/INST-1052 LI-926 LI-928 0-100% 5% RNP-I/INST-1052 Ll-930

9. SI Accumulator Pressure (TRMS TR 4.2.1)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER P1-92 1 0-800 psig 40 psig P1-923 RNP-I/INST-1036 P1-925 0-800 psig 40 psig P1-927 RNP-I/INST-1036 P1-929 0-800 psig 40 psig P1-93 1 RNP-I/INST-1036 OST-020 Rev. 41 Page 22 of 54

Section 8.2 Page 13 of 17 8.2 (Continued)

J.N1I i.NiI 07-19 19-07 8.2.4 IF MODE 1, 2, 3 OR 4 shiftly checks are required, THEN PERFORM CHANNEL CHECK for the following:

NOTE: The following check is to determine the deviation between the highest and lowest channel of redundant indicators for the same parameter. The redundant indicators to be compared are grouped in blocks. If the actual deviation is greater than the maximum allowed deviation as shown (deviation of 5% of the full range of the indicators movement), it is unacceptable.

1. CV Pressure (ITS SR 3.3.2.1, Table 3.3.2-1 Item 1.c, 2.c, 3.b.3 and 4.c)

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER PI-950A RNP-I/INST-1044 P1-951 P1-952 -5 75 psig 4 psig P1-953 P1-954 P1-955 OST-020 Rev. 41 Page 23 of 54

Section 8.2 Page 14 of 17 8.2.4 (Continued) iNil INil 07-19 19-07

2. PZR Pressure IF RCS pressure is outside the indicating range due to normal plant conditions, THEN mark N/A.

IN STRUM ENT IN STRUM ENT MAXIMUM CALCU LATI ON RANGE DEVIATION NUMBER P1-500 200-600psig 20 psig RNP-I/INST-1127 PI-501A

1) IF RCS pressure is outside the indicating range due to normal plant conditions, THEN mark N/A.

INSTRUMENT INSTRUMENT MAXIMUM CALCULATION RANGE DEVIATION NUMBER P1-444 1700-2500 psig 40 psig RNP-I/INST-1042 P1-445 NOTE: The following instrument does not have a redundant indicat or; therefore Maximum Deviation values are not provided.

OP-920, Radiation Monitoring System, provides instructions for performing radiation monitor channel checks.

3. Control Room Radiation Monitor R (ITS SR 3.3.7.1, Table 3.3.7-1 Item 2)

OST-020 Rev. 41 Page 24 of 54

Section 8.2 Page 15 of 17 8.2 (Continued)

NOTE: Per Calculation RNP-l/INST-1134 and Engineering determination NCR 00268640, the following Channel Check Acceptance from Criteria has been deemed appropriate for the Reactor Protection Source Range Instrum entation:

Source Range: The logarithmic value of the lowest indication subtracted from the logarithmic value of the highest indication SHALL be 1.48.

Due to the difficulty in reading a logarithmic meter with a fluctua ting signal, the digital indication from ERFIS or NR-45 should be used to perform the Channel Checks whenever possible.

The LOG function of an available calculator or the scientific calculator on the Control Room PC may be used to determine the logarithmic values.

(NCR 268640) 8.2.5 IF MODE 3, 4 OR 5 shiftly checks are required, THEN PERFORM CHANNEL CHECK on the Source Range Neutron Flux monitors. (ITS SR 3.3.1.1, Table 3.3.1-1 Item 4)

INIT 07-19

1. Day Shift (07-19)

a. RECORD NI-31 indication.

b. RECORD N-32 indication.

c. CALCULATE deviation: LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results: SAT I UNSAT (Circle one)

OST-020 Rev. 41 Page 25 of 54

Section 8.2 Page 16 of 17 8.2.5 (continued)

INIT 19-07

2. Night Shift (19-07)

a. RECORD NI-31 indication.

b. RECORD Nl-32 indication.

c. CALCULATE deviation: LOG (highest) minus LOG (lowest) equals:

d. PEER CHECK calculation.

e. DOCUMENT results. SAT I UNSAT OST-020 Rev. 41 Page 26 of 54

Section 8.2 Page 17 of 17 8.2 (Continued)

INIT INIT 07-19 19-07 8.2.6 IF movement of irradiated fuel assemblies in Spent Fuel Building OR Containment is occurring OR will occur, THEN PERFORM CHANNEL CHECK on the Control Roo m

Radiation Monitor- R-1. (ITS SR 3.3.7.1, Table 3.3.7

-1 Item 2) 8.2.7 IF the DSC is loaded OR being loaded AND is NOT seale d

lAW ISFS-014, THEN PERFORM CHANNEL CHECK on the Control Room Radiation Monitor R-1 until notified by maintenance that the sealing operation is complete.

(ITS SR 3.3.7.1, Table 3.3.7-1 Item 2)

NOTE: ITS 3.3.6.1 and Table 3.3.6-1, Containment Ventilation Isola Instrumentation, is applicable in modes 1, 2, 3, 4 OR tion during movement of RECENTLY irradiated fuel (decay time of less than 56 hour6.481481e-4 days 0.0156 hours 9.259259e-5 weeks 2.1308e-5 months s). Fuel is no longer recently irradiated if greater than 56 hours6.481481e-4 days 0.0156 hours 9.259259e-5 weeks 2.1308e-5 months have elapsed since reactor shutdown.

OP-920, Radiation Monitoring System, provides instructio ns for performing radiation monitor channel checks.

8.2.8 IF MODE 1, 2, 3, OR 4 shift checks are required, OR movement of RECENTLY irradiated fuel assemblies in Containment is occurring OR will occur, THEN PERFOR Ma CHANNEL CHECK on the Containment Radiation mon itors.

(ITS SR 3.3.6.1, Table 3.3.6-1 Item 3.a and 3.b)

- R-1 1, CV AIR & PLANT VENT PARTICULATE

- R-12, CV AIR & PLANT VENT RADIOACTIVE GAS OST-020 Rev. 41 Page 27 of 54

Section 8.3 Page 1 of 13 INIT INIT 07-19 19-07 8.3 Reactor Coolant System 8.3.1 IF MODE I shiftly checks are required, THEN PERFO RM the following:

1. VERIFY PZR Pressure is greater than or equal to 2205 psig. (ITS SR 3.4.1.1)

(07-19) psig (19-07) psig

2. VERIFY RCS Average Temperature is less than or equal to 57940 F. (ITS SR 3.4.1.2)

(07-19) °F (19-07)

OST-020 Rev. 41 Page 28 of 54

Section 8.3 Page 2 of 13 8.3.1 (Continued)

INIT INIT 07-19 19-07 NOTE: ITS SR 3.4.1.3 requires that the RCS Total Flow be verified to be greater than or equal to 6 97.3x10 Ibm/hr every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . RCS flow is not indicated in Ibm/hr Therefore, EST-047 was performed and provided the following values for performing this SR.

LOOP A LOOP B LOOP C Transmitter Mm Flow Transmitter Mm Flow Transmitter Mm Flow FT-414 98.81 FT-424 97.72 FT-434 101.94 FT-415 9881 FT-425 97.04 FT-435 101.86 FT-416 98.76 FT-426 95.61 FT-436 102.26

3. IF ERFIS is available, THEN VERIFY RCS flow indicated on ERFIS is greater than the Mm Flow values provided. (ITS SR 3.4.1.3)

LOOP A LOOP B LOOP C Transmitter Flow Transmitter Flow Transmitter Flow 07 19 07 19 07 19 RCFO400A RCFO42OA RCFO44OA (FT-414) (FT-424) (FT-434)

RCFO4OIA RCFO42IA RCFO441A (FT-41 5) (FT-425) (FT-435)

RCFO4O2A RCFO422A RCFO442A (FT-416) (FT-426) (FT-436)

OST-020 Rev. 41 Page 29 of 54

Section 8.3 Page 3 of 13 8.3.1 (Continued)

INIT INIT 07-19 19-07 NOTE: ITS SR 3.4.1.3 requires that the RCS Total Flow be verifie than or equal to 6 d to be greater 97.3x10 Ibm/hr every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . RCS flow is not indicat Therefore, EST-047 was performed and provided the follow ed in Ibm/hr.

ing values for performing this SR.

LOOP A LOOP B LOOP C Transmitter Mm Flow Transmitter Mm Flow Transmitter Mm Flow FT-414 98.81 FT-424 97.72 FT-434 101.94 FT-415 98.81 FT-425 97.04 FT-435 101.86 FT-416 98.76 FT-426 95.61 FT-436 102.26 NOTE: The marked increments of the RCS flow indicators on the This means they can not be read in less than 1% increments. RTGB are 2%.

4. IF ERFIS is unavailable, THEN VERIFY RCS flow as follows: (ITS SR 3.4.1.3)

a. RECORD RCS flow as indicated on the RTGB.

LOOP A LOOP B LOOP C Transmitter Flow Transmitter Flow Transmitter Flow 07 19 07 19 FT-4 14 07 19 FT-424 FT-434 (RCFO400A) (RCFO42OA) (RCFO44OA)

FT-4 15 FT-425 (RCFO4OIA) FT-435 (RCFO421A) (RCFO441A)

FT-416 FT-426 FT-436 (RCFO4O2A) (RCFO422A) (RCFO442A)

OST-020 Rev. 41 Page 30 of 54

Section 8.3 Page 4 of 13 INIT INIT 8.3.1.4 (Continued) 07-19 19-07

b. IF any RTGB RCS flow indication for Loop I and Loop 2 is less than 100%, OR IF any RTGB RCS flow indication for Loop 3 is less than 101%, THEN contact RES for assistance in verifying RCS flow.

RESS Contact (Print name) 8.3.2 IF MODE 1 OR 2 shiftly checks are required, THEN VERIFY each RCS Loop is in operation. (ITS SR 3.4.4.1) 8.3.3 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM the following:

NOTE: PZR Level limits are 63.3% when in MODE 1 and 92% when in MODE 2 OR 3.

1. VERIFY PZR Level is within limits.

(ITSSR3.4.9.1) (07-19) %

(19-07) %

NOTE: OP-920, Radiation Monitoring System, provides instructions for performing radiation monitor channel checks.

8.3.4 IF MODE 1, 2, 3 OR 4 shHtly checks are required, THEN PERFORM the following:

1. CHANNEL CHECK of the required CV Atmosphere Radioactivity Monitor. (ITS SR 3.4.15.1)

(07-19) Required Monitor R-11 / R-12 (Circle one)

(07-19) CHANNEL CHECK Complete (19-07) Required Monitor R-11 I R-12 (Circle one)

(19-07) CHANNEL CHECK Complete OST-020 Rev. 41 Page 31 of 54

Section 8.3 Page 5 of 13 8.3.4 (Continued) INIT 07-19

2. VERIFY Seal Injection flow of greater than or equal to 6 gpm to each RCP. (ITS SR 3.4.17.1) 07-19 Fl-130, RCP A gpm FI-127, RCP B gpm Fl-124, RCP C gpm NOTE: IF FI-127, FI-124 OR Fl-i 30 is OCS THEN manual calculation of Seal Injection Flow can be performed lAW OP-30i-1 to satisfy ITS SR 3.4.17.1. (ESR 99-00220)

IF Fl-i 30 is OOS, THEN notify maintenance to PERFORM PM 57033. (ITS LCO 3.4.17)

IF Fl-i 27 is DOS, THEN notify Maintenance to PERFORM PM 57032. (ITS LCD 3.4.17)

IF Fl-i 24 is DOS, THEN notify Maintenance to PERFORM PM 57031. (ITS LCD 3.4.17)

OST-020 Rev. 41 Page 32 of 54

Section 8.3 Page 6 of 13 8.3.4.2 (Continued) INIT 19-07 19-07 FI-130, RCP A gpm FI-127, RCP B gpm FI-124, RCP C gpm NOTE: IF FI-127, FI-124 OR FI-130 is OOS THEN manual calculation of Seal Injection Flow can be performed lAW OP-301-1 to satisfy ITS SR 3.4.17.1.

(ESR 99-00220)

IF Fl-i 30 is QOS, THEN notify maintenance to PERFORM PM 57033. (ITS LCO 3.4.17)

IF Fl-i 27 is OOS, THEN notify Maintenance to PERFORM PM 57032. (ITS LCO 3.4.17)

IF Fl-i 24 is OOS, THEN notify Maintenance to PERFORM PM 57031. (ITS LCO 3.4.17)

OST-020 Rev. 41 Page 33 of 54

Section 8.3 Page 7 of 13 INIT INIT 07-19 19-07 8.3.5 IF MODE 3 shiftly checks are required, THEN PERFORM the following:

VERIFY required RCS Loops are in operation.

(ITS SR 3.4.5.1)

2. VERIFY S/G secondary side water levels are greater than or equal to 16% NR for required RCS Loops.

(ITS SR 3.4.5.2) 07-19 SIG A %

SIG B %

SIG C %

19-07 SIG A %

SIG B %

S/G C %

3. IF only one RCS loop is in operation, THEN PERFORM ONE of the following:

a. VERIFY the Rod Control System is not capable of rod withdrawal. (ITS SR 3.4.5.3)

b. VERIFY the Reactor Trip Breakers are open.

(ITS SR 3.4.5.4)

c. VERIFY the Lift Coil Disconnect Switches for all Control Rods not fully withdrawn are open.

(ITS SR 3.4.5.5)

OST-020 Rev. 41 Page 34 of 54

Section 8.3 Page 8 of 13 INIT INIT 07-19 19-07 8.3.6 IF MODE 4 shiftly checks are required, THEN PERFORM the following:

VERIFY one RHR train OR RCS Loop is in operation.

(ITS SR 3.4.6.1) (07-19) RHR / RCS (Circle one)

(19-07) RHR/RCS (Circle one)

2. VERIFY S/G secondary side water levels are greater than or equal to 16% NR for required RCS loops.

(ITS SR 3.4.6.2)

(0719) A! B / C (Circle one)

(1907) A! B I C %

(Circle one)

OST-020 Rev. 41 Page 35 of 54

Section 8.3 Page 9 of 13 INIT INIT 07-19 19-07 NOTE: Steps 8.3.7 OR 8.3.8, along with step 8.3.9, are required to meet Low Temperature Overpressure Protection (LTOP) requirements of ITS LCO 3.4.12 in MODES 4 and 5.

When in MODES 4 OR 5, an OPERABLE Power Operated Relief Valve (PORV) will have a nominal lift setting of 400 psig and an allowed value of 41 8 psig.

8.3.7 IF MODE 4 OR 5 shiftly checks are required, and use of OPERABLE Power Operated Relief Valves is desired to meet Low Temperature Overpressure Protection per ITS LCO 3.4.12.a, THEN VERIFY the following:

1. Two Power Operated Relief Valves (PORV5) are operable and each associated PORV block valve is OPEN.

PCV-456, PZR PORV (07-19) OPERABLE RC-535, PORV BLOCK (07-19) OPEN PCV-455C, PZR PORV (07-19) OPERABLE RC-536, PORV BLOCK (07-19) OPEN PCV-456, PZR PORV (19-07) OPERABLE RC-535, PORV BLOCK (19-07) OPEN PCV-455C, PZR PORV (19-07) OPERABLE RC-536, PORV BLOCK (19-07) OPEN

2. A maximum of one Safety Injection (SI) pump capable of injecting into the RCS when all cold leg temperatures are 175°F.

3. No SI pump capable of injecting into the RCS when any cold leg temperature is <1 75°F.

OST-020 Rev. 41 Page 36 of 54

Section 8.3 Page 10 of 13 NOTE: ITS Bases for LCO 3.4.12 states for an RCS Vent to meet the flow capacity requirement, it requires removing a pressurizer safety valve, removing a PORVs internals or physically blocking the valve stem of the PORV in the open position, and disabling its block valve in the open position. ITS LCO 3.4.12.b identifies that the required vent size for the RCS to be considered vented is greater than or equal to 4.4 square inches. One safety valve removed provides an opening greater than 10 square inches. Both PORVs Blocked Open with the Block Valves Open are required to meet the 4.4 square inches.

The required frequency for ITS SR 3.4.12.5 is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . This SR is performed shiftly for ease of tracking, since there is no OST which is performed on a 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months frequency.

INIT INIT 07-19 19-07 8.3.8 IF MODE 4 OR 5 shiftly checks are required, and use of a depressurized RCS with a vent path of 4.4 square inches, is desired to meet Low Temperature Overpressure Protection per ITS LCO 3.4.12.b, THEN VERIFY the following:

1. IF using Safety Valve Removed to comply with ITS LCO 3.4.12.b, THEN VERIFY at least ONE Safety Valve removed and FME cover not restricting flow.

a. RC-551A I RC-551 B I RC-551C Circle One Removed (07-19)

b. RC-551A I RC-551 B I RC-551 C Circle One Removed (19-07)

OST-020 Rev. 41 Page 37 of 54

Section 8.3 Page 11 of 13 8.3.8 (continued) INIT INIT 07-19 19-07

2. IF using PORVs to comply with ITS LCO 3.4.12.b, THEN VERIFY both PZR PORVs are BLOCKED OPEN lAW OP-006 AND the associated Block Valves are OPEN.

PCV-456, PZR PORV (07-19) BLOCKED OPEN RC-535, PORV BLOCK (07-19) OPEN

- PCV-455C, PZR PORV (07-19) BLOCKED OPEN RC-536, PORV BLOCK (07-19) OPEN PCV-456, PZR PORV (19-07) BLOCKED OPEN RC-535, PORV BLOCK (19-07) OPEN PCV-455C, PZR PORV (19-07) BLOCKED OPEN RC-536, PORV BLOCK (19-07) OPEN OST-020 Rev. 41 Page 38 of 54

Section 8.3 Page 12 of 13 INIT INIT 07-19 19-07 NOTE: ITS LCO 3.4.12 contains a Note which amplifies when SI Accumulators are required to be isolated. The following step is a simplified method to ensure compliance and eliminates the need to use ITS LCO 3.4.3 curves.

8.3.9 IF MODE 4 OR 5 shiftly checks are required and any SI Accumulator is pressurized, THEN VERIFY each SI Accumulator isolation valve is closed AND deenergized for Low Temperature Overpressure Protection.

(ITS SR 3.4.12.3)

1. SI Accumulator A Sl-865A, ACCUMULATOR A DISCHARGE (07-19) CLOSED (19-07) CLOSED

- SI-865A, ACCUMULATOR A DISCHARGE breaker on MCC-5, CMPT 14F (07-19) OPEN (19-07) OPEN

2. SI Accumulator B

- SI-865B, ACCUMULATOR B DISCHARGE (07-19) CLOSED (19-07) CLOSED SI-865B, ACCUMULATOR B DISCHARGE breaker on MCC-6, CMPT IOJ (07-19) OPEN (19-07) OPEN OST-020 Rev. 41 Page 39 of 54

Section 8.3 Page 13 of 13 8.3.9 (Continued) INIT INIT 07-19 19-07

3. SI Accumulator C SI-865C, ACCUMULATOR C DISCHARGE (07-19) CLOSED (19-07) CLOSED SI-865C, ACCUMULATOR C DISCHARGE breaker on MCC-5, CMPT 9F (07-19) OPEN (19-07) OPEN 8.3.10 IF MODE 5 shiftly checks are required, THEN PERFORM the following:

VERIFY one RHR Train is in operation.

(ITS SR 3.4.7.1 and 3.4.8.1) (07-19) A / B (Circle one)

(19-07) A I B (Circle one)

2. IF RCS loops are filled AND only one RHR train is operable, THEN VERIFY SIG secondary side water level is greater than or equal to 16% NR in the required S/G. (ITS SR 3.4.7.2)

(0719) A I B I C (Circle one)

(1907) A I B I C (Circle one)

OST-020 Rev. 41 Page 40 of 54

Section 8.4 Page 1 of 4 INIT INIT 07-19 19-07 8.4 Emergency Core Cooling Systems 8.4.1 IF MODE 1, 2 OR 3 shiftly checks are required, THEN PERFORM the following:

IF RCS pressure is greater than 1000 psig, THEN PERFORM the following:

a. VERIFY Borated Water Volume in each SI Accumulator is greater than or equal to 825 ft 3 (61.5%) and less than or equal to 841 ft 3 (80.4%). (ITS SR 3.5.1.2)

SI Accumulator A (07-19) %

SI Accumulator B (07-19) %

SI Accumulator C (07-19) %

SI Accumulator A (19-07) %

SI Accumulator B (19-07) %

SI Accumulator C (19-07) %

OST-020 Rev. 41 Page 41 of 54

Section 8.4 Page 2 of 4 8.4.1.1 (Continued) INIT INIT 07-19 19-07

b. VERIFY Nitrogen Cover pressure in each SI Accumulator is greater than or equal to 600 psig and less than or equal to 660 psig.

(ITS SR 3.5.1.3)

SI Accumulator A (07-19) psig SI Accumulator B (07-19) psig SI Accumulator C (07-19) psig SI Accumulator A (19-07) psig SI Accumulator B (19-07) psig SI Accumulator C (19-07) psig OST-020 Rev. 41 Page 42 of 54

Section 8.4 Page 3 of 4 8.4.1 (Continued) thu 07-19 19-07

2. VERIFY the following valves are in the listed positions with Control Power to the valve operator removed.

(ITS SR 3.5.21)

SI-862A, RWST to RHR OPEN SI-862B, RWST to RHR OPEN

- Sl-863A, RHR LOOP RECIRC CLOSED SI-863B, RHR LOOP RECIRC CLOSED Sl-864A, RWST DISCH OPEN SI-864B, RWST DISCH OPEN Sl-866A, LOOP 3 HOT LEG INJ CLOSED Sl-866B, LOOP 2 HOT LEG INJ CLOSED

- Sl-878A, SI DISCH CROSS CONN OPEN

- SI-878B, SI DISCH CROSS CONN OPEN SI-862A AC Control Power Defeat Switch Defeated Sl-862B AC Control Power Defeat Switch Defeated OST-020 Rev. 41 Page 43 of 54

Section 8.4 Page 4 of 4 8.4.1.2 (Continued)

UJI NEL 07-19 19-07 SI-863A AC Control Power Defeat Switch Defeated SI-863B AC Control Power Defeat Switch Defeated Sl-864A AC Control Power Defeat Switch Defeated Sl-864B AC Control Power Defeat Switch Defeated SI-866A AC Control Power Defeat Switch Defeated Sl-866B AC Control Power Defeat Switch Defeated SI-878A breaker on MCC-5 in CMPT No. 2C OPEN Sl-878B breaker on MCC-6 in CMPT NO. 15C OPEN OST-020 Rev. 41 Page 44 of 54

Section 8.5 Page 1 of I INIT INIT 07-19 19-07 8.5 Containment Systems 8.5.1 IF MODE 1, 2, 3 OR 4 shiftly checks are required, THEN PERFORM the following:

VERIFY CV Pressure is greater than or equal to

-0.8 psig and less than or equal to 1.0 psig.

(ITS SR 3.6.4.1)

(07-19) psig (19-07) psig

2. VERIFY IVSW Tank Pressure is greater than or equal to 49 psig (includes instrument uncertainties)

(NCR 188409) indicated locally on P1-i 910 OR as indicated on a locally installed temporary gage with an accuracy equal to or less than +/-2 psig.

(ITS SR 3.6.8.1)

(07-19) psig (19-07) psig OST-020 Rev. 41 Page 45 of 54

Section 8.6 Page 1 of I INIT INIT 07-19 19-07 8.6 Plant Systems 8.6.1 IF MODE 1,2, 3 shiftly checks are required OR mode 4 shiftly checks are required when any S/G is being used for heat removal, THEN PERFORM the following:

NOTE: 8S19-P-101 allows 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of operation with CST level between 50%

and 26%.

If LI-i 454A or LI-1454B is unavailable, Ll-1454C may be used to check CST level.

CST level indications used should be within 5% of one another to satisfy OST-023 and OST-918 requirements. (ITS 3.3.3 Table 3.3.3-1 item 14.)

1. VERIFY CST Level is greater than or equal to 50%. (Admin.

limit per 8519-P-Id & Appendix R Separation Analysis)

(ITS SR 3.7.5.1 limit of 35,000 gallons (26%)).

Ll-1454A (07-19)

Ll-1454B (07-19)

LI-1454A (19-07)

Ll-i454B (19-07) 8.6.2 IF MODE 1, 2, 3, 4, OR 5 shiftly checks are required, OR during movement of irradiated fuel assemblies, THEN PERFORM the following:

1. VERIFY Control Room temperature is less than or equal to 85°F using TIC-6513 if available OR a calibrated thermometer placed near the return duct inlet. (TRMS TR 4.7.1)

(07-19) TIC-6513 (19-07) TIC-6513 Calibrated Thermometer (07-19)

Calibrated Thermometer (19-07)

OST-020 Rev. 41 Page 46 of 54

Section 8.7 Page 1 of 4 INIT INIT 07-19 19-07 8.7 Other 8.7.1 IF MODE 1, 2, 3,4 OR 5 shiftly checks are required, THEN VERIFY the following Dedicated Shutdown/SBO Equipment:

1. DS Diesel Fuel Oil Storage Tank level greater than or equal to 2500 gallons. (07-19) gal (19-07) gal OST-020 Rev. 41 Page 47 of 54

Section 8.7 Page 2 of 4 INIT INIT 07-19 19-07 NOTE: This section should be performed during dayshift when Unit 1 Chemistry personnel will be available.

8.7.2 IF Mode 1, 2, 3, OR 4 daily checks are required, THEN PERFORM the following:

1. RECORD the ERFIS reading for CWT9O21A, Black Creek Temperature. °F N/A NOTE: Reviewing the Circulating Water Effluent Monitoring Log hourly print out will aid in performance of this step.

2. RECORD ERFIS reading for CWT2400A, TE-3091A, COND A CW Inlet Temp N/A

3. COMPARE ERFIS point CWT9O21A, Black Creek Temperature, to the temperature in 8.7.2.2 AND RECORD the difference.

[CAPR, NCR 00290724] °F N/A NOTE: Temperature indication will not be reliable if there is no circulating water flow (i.e. water box not in service). Additionally a margin of 3°F OR greater could be caused by wind direction, lake level, and stratification due to rainfall, or other possible causes. No additional checks required when differences can be explained and no instrument failures suspected.

4. IF CWT9O2IA varies from ERFIS point CWT2400A by 3°F OR greater AND cannot be explained, THEN PERFORM the following:

a. REQUEST Unit 1 Control Room to have Unit 1 Chemistry personnel CHECK local temperature using a calibrated temperature instrument for comparison. N/A OST-020 Rev. 41 Page 48 of 54

Section 8.7 Page 3 of 4 8.7.2.4 (Continued)

INIT INIT 07-19 19-07 NOTE: The following step requires that a WR be initiated for the suspect instrument when the margin is 2°F or greater between ERFIS point CWT9O21A and the calibrated temperature instrument. However, latitude should be given to reflect that the two instruments may not take temperatures in the same location in the flow stream and as such are affected by stratification caused by a rise in tail flow and associated rainfall. A work request is not needed when the difference can be explained and no instrument failure is suspect.

b. IF a delta of 2°F OR more is observed between ERFIS point CWT9O2IA AND the calibrated temperature instrument, THEN INITIATE a work request for the suspect temperature instrument AND perform all applicable actions of PLP-023. W/R# N/A

5. RECORD the ERFIS reading for CWT9O22A, Discharge Canal Weir temperature. °F N/A NOTE: Step 8.7.2.6 may be performed by contacting the Unit I Control Room.

6. From Unit 1 Control Board Indication for Discharge Canal Weir temperature, RECORD the temperature.

°F N/A OST-020 Rev. 41 Page 49 of 54

Section 8.7 Page 4 of 4 INIT INIT 07-19 19-07 8.7.2 (Continued)

7. PERFORM a channel check on ERFIS point CWT9O22A, Discharge Canal Weir temperature, by comparing to the reading from the Unit 1 Control Board Indication for Discharge Canal Weir temperature AND RECORD the difference.

[CAPR NCR 290724] °F___ N/A

8. IF CWT9O22A varies from the Unit I Control Board Indication by 3 degrees OR greater AND the delta cannot be explained, THEN PERFORM the following:

a. REQUEST Unit I Control Room to have Unit 1 Chemistry personnel CHECK local temperature using a calibrated temperature instrument for comparison. N/A NOTE: The following step requires that a WR be initiated for the suspect instrument when the margin is 2°F or greater between ERFIS point CWT9O22A and the calibrated temperature instrument. However, latitude should be given to reflect that the two instruments may not take temperatures in the same location in the flow stream and as such are affected by stratification caused by a rise in tail flow and associated rainfall. A work request is not needed when the difference can be explained and no instrument failure is suspect.

b. IF a delta of 2 degrees OR more is observed between ERFIS point CWT9O22A AND the calibrated temperature instrument, THEN INITIATE a work request for the suspect temperature instrument.

W/R#

N/A OST-020 Rev. 41 Page 50 of 54

Section 8.7 Page 4 of 4 INIT INIT NOTE: When the SI accumulators are pressurized AND Boron Injection to RCS Check Valve leakage is present this section should be performed to maintain the BIT header pressure above 650 psig. (SI-873C1SI-873F, SI-873B/SI-873E, OR SI-873A1S1-873D)

APP-002-C3, BIT HDR HI PRESS, provides guidance for draining the BIT line via an SI pump(s) to relieve the BIT Header pressure.

OP-202-1, SI System Venting, provides guidance to re-pressurize the BIT header if it becomes necessary.

PT-943 and PT-940 can be used to trend pressure changes which would indicate potential leakage into and out of the piping sections.

8.7.3 IF Accumulator to SI check valves leakage is present, THEN PERFORM the following:

1. CHECK AND RECORD BIT Header Pressure (P1-934).

(07-19) psig (19-07) psig

2. IF BIT Header Pressure (P1-934) is less than 650 psig, THEN PERFORM OP-202-1, Section 8.15.

(07-19)

(19-07)

OST-020 Rev. 41 Page 51 of 54

9.0 RECORDS 9.1 The completed procedure and any partials are forwarded to Plant Records.

10.0 ATTACHMENTS 10.1 Surveillance Test Procedure Certification and Review Form (Shift 07-19) 10.2 Surveillance Test Procedure Certification and Review Form (Shift 19-07)

OST-020 Rev. 41 Page 52 of 54

ATTACHMENT 10.1 Page 1 of 1 SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM SHIFT 07-19 Scheduled I Unscheduled (Circle one)

(If unscheduled, state reason for test and the page numbers included in partial test)

Initials Name (Print) Date Test Performed By:

Test Complete: Date: Time:_____________

Test Satisfactory: Yes / No (Circle one)

Reviewed by:

Shift Technical Advisor Date Comments: (Required if results were unsatisfactory)

Approved by:

Shift Manager Date OST-020 Rev. 41 Page 53 of 54

ATTACHMENT 10.2 Page 1 of I SURVEILLANCE TEST PROCEDURE CERTIFICATION AND REVIEW FORM SHIFT 19-07 Scheduled / Unscheduled (Circle one)

(If unscheduled, state reason for test and the page numbers included in partial test)

Initials Name (Print) Date Test Performed By:

Test Complete: Date: Time:_____________

Test Satisfactory: Yes / No (Circle one)

Reviewed by:

Shift Technical Advisor Date Comments: (Required if results were unsatisfactory)

Approved by:

Shift Manager Date OST-020 Rev. 41 Page 54 of 54

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Appendix C Job Performance Measure Form ES-C-i Worksheet Facility: HB ROBINSON Task No.: 02344100403 Task

Title:

Calculate Emergency Dose JPM No.: 2011-2 NRC Admin JPM Exposure Time Limits SRO A3 K/A

Reference:

G2.3.4 3.2/3.7 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Initial Conditions:

An Emergency Event has been declared.

Re-entry individual has received 1240 mR TEDE dose this year at RNP.

There are 2 jobs that must be performed to stabilize the plant and protect the equipment:

o Valve LCV-1 1 5B, RWST to Charging Pump Suction, air line needs to be re-attached to the valve operator.

o Seal Injection Filter B must be placed in service due to Filter A clogged.

All valves are located in a 48 R/hr field.

Task Standard: Determines Stay Time Required Materials: Calculator EPOSC-04, EMERGENCY WORK CONTROL General

References:

EPOSC-04, EMERGENCY WORK CONTROL Handouts: NONE 2011-2 NRC Admin JPM SRO A3 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-i Worksheet Initiating Cue: Calculate how long the individual can remain in the radiation area without exceeding the applicable emergency exposure limits.

Time Critical Task: NO Validation Time: 8 minutes 2011-2 NRC Admin JPM SROA3 NUREG 1021, Revision 9, Supplement i

Appendix C Page 3 of 6 Form ES-C-i PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk *

)

Start Time:

EPOSC-04, EMERGENCY WORK CONTROL

Performance Step: I The table shown below identifies the emergency work er dose limits. In addition to the categories listed in the table

, doses should be limited as follows:

1. The lens of the eye should be limited to three (3) time s

the stated TEDE value.

2. Any other organ (including skin and body extremitie s) should be limited to ten (10) times the stated TEDE valu e.

(Step 8.7.2)

Dose Limit Activity Condition 5 REM All 10 REM Repair and reentry Lower dose not practical efforts 25 REM Lifesaving or Lower dose not practical protection of large populations

>25 REM Lifesaving or Only on a voluntary basis protection of large to persons fully aware of populations the risks involved Standard: Candidate selects 10 REM Dose Limit for Repair effor ts Examiners Cue:

Examiners Note:

Comment:

2011-2 NRC Admin JPM SROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 4 of 6 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 2 10R HR 60 Mm 48R HR = 12.5 Minutes Dose Dose Conversion Time Limit Limit Rate Standard: Candidate calculates 12.5 minutes total stay time.

Examiners Cue:

Comment:

END OF TASK Terminating Cue: Candidate calculates Stay Time STOP TIME:

2011-2 NRC Admin JPM SRO A3 NUREG 1021, Revision 9, Supplement I

Appendix C Page 5 of 6 Form ES-C-i VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC Admin JPM SRO A3 Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

Response

Result: SAT UNSAT Examiners Signature: Date:

20i1-2 NRC Admin JPM SROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C -

Page 6 of 6 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

An Emergency Event has been declared.

Re-entry individual has received 1240 mR TEDE dose this year at RNP.

There are 2 jobs that must be performed to stabi lize the plant and protect the equipment:

o Valve LCV-1 1 5B, RWST to Charging Pump Suction, air line needs to be re-attached to the valve operator.

o Seal Injection Filter B must be placed in service due to Filter A clogged.

All valves are located in a 48 R/hr field.

Initiating Cue: Calculate how long the individual can remain in the radia tion area without exceeding the applicable emergency exposure limits.

2011-2 NRC Admin JPM SROA3 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 6 of 6 Form ES-C-i JPM CUE SHEET INITIAL CONDITIONS:

An Emergency Event has been declared.

Re-entry individual has received 1240 mR TED E dose this year at RNP.

There are 2 jobs that must be performed to stabi lize the plant and protect the equipment:

o Valve LCV-115B, RWST to Charging Pump Suct ion, air line needs to be re-attached to the valve operator.

o Seal Injection Filter B must be placed in service due to Filter A clogged.

All valves are located in a 48 R/hr field.

Initiating Cue: Calculate how long the individual can remain in the radiation area without exceeding the applicable emergency expo sure limits.

2011-2 NRC Admin JPM SRO A3 NUREG 1021, Revision 9, Supplement I

Appendix C Job Performance Measure Form ES-C-I Worksheet Facility: HB ROBINSON Task No.: 02344101203 Task

Title:

Classify an Emergency Event JPM No.: 201 1-2 NRC JPM Admin SROA4 K/A

Reference:

G2.4.41 (2.9/4.6)

Examinee: NRC Examiner:

Facility Evaluator Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide you complete the task successfully, the objective for this Job Performance Measu initiating cues. When re will be satisfied.

Initial Conditions:

This is a DRILL.

Unit at 30% RTP with a shutdown in progress lAW GP-006.

CV Purge is in progress to support upcoming maintenance activities inside the CV.

CV Spray Pump A is inoperable due to a grounded motor.

Subsequently, a LOCA and loss of offsite power occurred at 1021 hours0.0118 days 0.284 hours 0.00169 weeks 3.884905e-4 months on 11)28/2011.

Emergency Diesel Generator B trips while starting.

CV pressure peaked at 37 psig.

Core exit thermocouples are currently reading 304°F.

R-32A is reading 8 Rem/hr.

RVLIS indication reads 45%.

S/G NR levels are currently at A-12%, B-15%, C-32%.

Weather conditions: Wind direction is from 145 degrees, Wind speed is 4 mph, Stability Class is D, Precipitation is Zero.

You are the Shift Manager.

Task Standard: Identifies event as an SITE AREA EMERGENCY per FS1.1 Required Materials: EPCLA-01, EPCLA-04, EAL Matrixes, EPNOT-01.

General

References:

EPCLA-01, EPCLA-04, EAL Matrixes, EPNOT-01.

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement 1

Appendix C Job Performance Measure Form ES-C-I Worksheet Handouts: EPC-O1, EPC-O4, EAL Matrixes, EPNOT-O1.

Initiating Cue: Classify the event lAW the EAL matrixes. Upon completion of the event classification, inform the examiner.

This Task is TIME CRITICAL Time Critical Task: YES (15 minutes for classification AND 15 minutes for notific ation)

Validation Time: 24 minutes 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 3 of 14 Form ES-C-I PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk *

)

Start Time: Time Critical Start Time:________

Performance Step: I Obtain the EAL ALL Conditions and COLD Conditions Matrix Standard: Candidate states where to obtain the EALs.

Examiners NOTE: Provide copies of the EAL Matrix to the candidate.

Comment Performance Step: 2 EVALUATE ALL Conditions EAL Matrix under all conditions.

(Step 8.3.1)

Standard: Candidate reviews EAL ALL Conditions Matrix and does not identify any classification.

Examiners NOTE:

Comment:

201 1-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 4 of 14 Form ES-C-i PERFORMANCE INFORMATiON 0

Performance Step: 3 IF Reactor Coolant temperature is > 200°F, THEN EVAL UATE HOT Conditions EAL Matrix (Step 8.3.2)

Standard: Candidate reviews EAL HOT Conditions Matrix and identif ies the following classification: Site Area Emergency FSI.1 Loss or potential loss of any two barriers (Tab le F-I)

Reactor Coolant System Barrier

Loss I Containment High Range Monitor R-32A or R-32B >5 Remlhr.

OR

Loss 2 RCS leak rate> available makeup capacity as indicated by a loss of RCS subcooling less than 35°F

[55°9 OR

Potential Loss 2- Unisolable RCS leak exceeding the capacity of one charging pump (77 gpm)

Containment Barrier

Potential Loss 7 Containment pressure> 10 psig with <one full train of depressurization equipment operating. (Note: One Containment Spray System train and one Containment Cooling System train comprise one full train of depressurization equipment.)

Examiners NOTE: Candidate will declare a Site Area Emergency and prese nt his classification to you. This will stop the 15 minute clock for the declaration portion of the JPM.

Comment:

Time Critical Stop Time for EAL Classification:

(15 Minutes) 2011-2 NRC JPM Admiri SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 5 of 14 Form ES-C-I PERFORMANCE INFORMATION 0

Examiners CUE: Present the candidate with the second cue sheet for the JPM task of completing the Emergency Notification Form and a copy of procedure EPNOT-Oi.

Time Critical Start Time for EAL Notification:

Performance Step: 4 Candidate will proceed to Attachment 10.7 for a Site Area Emergency and direct the Emergency Communicator to report to the Control Room to assume the duties of the Emergency Communicator.

Standard: Candidate informs the Emergency Communicator to prepare for communication activities.

Examiners NOTE:

Examiners CUE: When the candidate has completed the EAL classification, CUE the candidate that he will manually complete an Emergency Notification Form and submit it to the SEC.

Comment 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 6 of 14 Form ES-C-I PERFORMANCE INFORMATION 0

Performance Step: 5 Obtain EPNOT-0I, Attachment 10.5, Nuclear Power Plant Emergency Notification Form.

Standard: Copies Attachment from procedure or pulls it from a file.

Examiners NOTE:

Examiners CUE: The Examiner will provide a copy of EPNOT-O1 to the candidate.

Comment:

Performance Step: 6 Enter Line I information.

Standard: Marks DRILL and Message # 1.

Examiners NOTE: Ensure that DRILL is marked. ACTUAL EVENT is only used during a real emergency.

Comment:

Performance Step: 7 Enter Line 2 information.

Standard: Marks INITIAL.

Examiners NOTE:

Comment:

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 7 of 14 Form ES-C-I PERFORMANCE INFORMATION C)

Performance Step: 8 Enter Line 3 information.

Standard: Enters H.B. Robinson as the Site and enters CONFIRMATION PHONE NUMBER.

Examiners NOTE: Identifying the site as H.B. Robinson is critical. Listing the proper confirmation telephone number Is NOT critical.

Examiners CUE: When candidate requests the ERO phone list, tell him the Confirmation Phone Number is 843-383-3685.

Comment

Performance Step: 9 Enter Line 4 information.

Standard: Marks SITE AREA EMERGENCY as the Emergency Classification.

Based on EAL # FSI.I EAL Description Loss or potential loss of any two barriers (Table F-I)

Examiners NOTE:

Comment:

Performance Step: 10 Enter Line 5, Protective Action Recommendation information.

Standard: Marks NONE.

Examiners NOTE:

Comment:

201 1-2 NRC JPMAdmin SROA4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 8 of 14 Form ES-C-i PERFORMANCE INFORMATION

Performance Step: 11 Enter Line 6, EMERGENCY RELEASE, information.

Standard: Marks NONE.

Examiners NOTE:

Comment:

Performance Step: 12 Enter Line 7, RELEASE SIGNIFICANCE, information.

Standard: Marks NOT APPLICABLE.

Examiners NOTE:

Examiners CUE:

Comment:

Performance Step: 13 Enter Line 8, EVENT PROGNOSIS, information.

Standard: Marks Degrading.

Examiners NOTE:

Comment 2011-2 NRC JPMAdmin SROA4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 9 of 14 Form ES-C-I PERFORMANCE INFORMATION

Performance Step: 14 Enter Line 9, METEROLOGICAL DATA, infor mation.

Standard:

Enters data that was given in the initial condition s:

Wind Direction 146 degrees, Wind Speed 4 mph, Precipitation 0, Stability Class D.

Examiners NOTE:

Comment

Performance Step: 15 Enter Line 10 INFORMATION.

Standard:

Marks Block A, DECLARATION: Enters appl icable Date and Time.

Examiners NOTE:

Examiners CUE: Date and time should reflect present date and time.

Comment Performance Step: 16 Enter Line 11 information, AFFECTED UNI TS.

Standard:

Marks UnIt 2.

Examiners NOTE:

Comment 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 10 of 14 Form ES-C-I PERFORMANCE INFORMATION ED Performance Step: 17 Enter Line 12 information UNIT STATUS.

Standard: Enters Shutdown Time: 1021 hours0.0118 days 0.284 hours 0.00169 weeks 3.884905e-4 months on 1112812011 Examiners NOTE: Reactor shutdown DATE and TIME was given in the initial conditions on the cue sheet.

Examiners CUE:

Comment:

Performance Step: 18 Enter Line 13 Remarks information.

Standard: Enters information describing accident from EAL matrix.

Examiners NOTE: May leave LINE 13, Remarks blank or enter EAL information.

Comment:

Performance Step: 19 Line 17 APPROVAL by SEC.

Standard: Completes Line 17 with Signature, Title, Time, and Date.

Examiners NOTE:

Comment:

Time Critical Stop Time for EAL Notification: (15 Minutes)

C 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement 1

Appendix C Page 11 of 14 Form ES-C-I PERFORMANCE INFORMATION 0

END OF TASK Termination Cue: EAL classification has been determined and notif ication has been made.

STOP TIME:

0 C

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 12 of 14 Form ES-C-I VERIFICATION OF COMPLETION Job Performance Measure No.: 2011-2 NRC JPM Admin SRO A4 Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Question:

0

Response

Result: SAT UNSAT Examiners Signature:

Date:

2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

/cc:7 ATTACHMENT 10.5 Page 1 of 11 NUCLEAR POWER PLANT EMERGE NCY NOTIFICATION FORM 1.3RlLL ACTUAL EVENT MESSAGE 2NITIAL Lf9.OWUP NOTIFICATION: TIME DATE I I

3. SITE: LL3 /OIAL?lJ AUTHENTICATION Confirmation Phone # ?43 33 ...3

4. EMERGENCY UNUSUAL EVENT CLASSIFICATiON; ALERT ITE AREA EMERGENCY GENERAL ADO4tiS EAL?ESQy:

t t

(

5. PROTECTIVE ACTION RECOMMENDATIO NS: 1 N ONE EVACUATE I

SHELTER CONSIDER THE USE OF KI (POTASSIUM IODIDE) IN ACCORDANCE wrn-i STAT E PtANS AND POLICY.

BOThER

6. EMERGENCY RELEASE: None ( is Occuning Has Occurred

7. RELEASE SIGNIFICANCE: Not plicabIe wittn normal Above normal operating Under operating limits Iirits evaluation

8. EVENT PROGNOSIS: Improving Sta, 1 ble Degrading

9. METEOROLOGICAL DATA: Wind Direction* from (if degrees , /

(.f..

(May not be available for Initial Vnd Speed* mph Notifiations) Preclpitation* C) Stability CIass*

1O.DECLARATION TERMINATION O 11. AFFECTED UNIT(S):

Time Date 1 7iI thtz

12. UNIT STATUS:

UI Por Shutdown at Time (Unaffected Unit(s) Status Not Required for Date _J_I_

Initial Notifications) 1J2 U3

% Por Shutdown at Time

% Pover Shutdown at Time

- ( Date LLii2jJ_i

13. REMARKS: Date _j_/_

FOLLOW-UP INFORMATION (Lines 14 throu gh 16 Not Required for Initial Notifications)

EMERGENCY RELEASE DATA. NOT REQU

14. RELEASE CHARACTERIZATION: IRED IF UNE 6 A is SELECTED.

TYPE; Elevated Mbced Ground UNITS: Ci MAGNiTUDE: Noble Gases:__________ lodine Ci/sec j.LCW5ec s:___________ Particulates:__________ Othe FORM: Airborne Start Time r Date _I I_Stop Time Date _i Start Time I_

Liquid Date _I_I__Stop lime Date _I_I_

15. PROJECTION PARAMETERS: Projection period: Estimated Release Duration Projection performed: Time Hours Date _l I.....

16. PROJECTED DOSE: DISTANCE TEDE (mRem) Adult Thyroid CDE (mRem)

Site boundary 2 Miles 5 Miles 0 Miles

17. APPROVED NOTIFIED BY:______________

Title A Ee. Time A10C4) DateTd RECEIVED BY: Time Date I

[EPNOT-01

( Rev. 37 Page 37 of 6!j

Appendix C Page 13 of 14 Form ES-C-I JPM CUE SHEET 0

INITIAL CONDITIONS:

This is a DRILL.

Unit at 30% RTP with a shutdown in progre ss lAW GP-006.

CV Purge is in progress to support upcoming maintenance activities inside the CV.

CV Spray Pump A is inoperable due to a grounded motor.

Subsequently, a LOCA and loss of offsite pow er occurred at 1021 hours0.0118 days 0.284 hours 0.00169 weeks 3.884905e-4 months on 11128/2011.

Emergency Diesel Generator B trips while starting.

CV pressure peaked at 37 psig.

Core exit thermocouples are currently reading 304°F.

R-32A is reading 8 Rem/hr.

RVUS indication reads 45%.

SIG NR levels are currently at A-12%, B-15

%, C-32%.

Weather conditions: Wind direction is from 145 degrees, Wind speed is 4 mph, Stability Class is 0, Precipitation is Zero.

You are the Shift Manager.

INITIATING CUE: Classify the event lAW the EAL matrixes.

Upon completion of the event classification, inform the examiner.

This Task is TIME CRITICAL 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

Appendix C Page 14 of 14 Form ES-C-i JPM CUE SHEET 0 INITIAL CONDITIONS: Emergency event has just been declared by the Control Room Site Emergency Coordinator (SEC).

INITIATING CUE: The Emergency Communicator is NOT available.

Control Room Site Emergency Coordinator (SEC You, as the

), must manually complete the Emergency Notification Form (ENF

) from procedure EPNOT-O1, CRIEOF Emergency Communicato r.

This task is TIME CRITICAL.

0 2011-2 NRC JPM Admin SRO A4 NUREG 1021, Revision 9, Supplement I

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